SYSTEMS AND METHODS FOR HYDRAULIC FRACTURING
An embodiment of a pumping unit includes a gas turbine engine, an enclosure housing the engine, an exhaust assembly connected to the engine, an air intake duct connected to the engine, and an air treatment system connected to the air intake duct. The air treatment system including one or more inlet pre-cleaners configured to eject debris. Each of the inlet pre-cleaners having a cylindrical tubular portion configured to channel air toward the air intake duct. In addition, the pumping unit includes a gearbox operatively coupled to the engine and a drive shaft having a first end operatively coupled to the gearbox. Further, the pumping unit includes a pump comprising an input shaft operatively coupled to a second end of the drive shaft, wherein the engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pumping unit.
This application is a continuation-in-part of U.S. Non-Provisional Application No. 18/148,209, filed Dec. 29, 2022, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/954,118, filed Sep. 27, 2022, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,598,263, issued Mar. 7, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/403,373, filed Aug. 16, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,560,845, issued Jan. 24, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/326,711, filed May 21, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,156,159, issued Oct. 26, 2021, which is a continuation U.S. Non-Provisional Application No. 17/213,802, filed Mar. 26, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,060,455, issued Jul. 13, 2021, which is a continuation of U.S. Non-Provisional Application No. 16/948,289, filed Sep. 11, 2020, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,002,189, issued May 11, 2021, which claims priority to and the benefit of U.S. Provisional Application No. 62/704,565, filed May 15, 2020, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” and U.S. Provisional Application No. 62/900,291, filed Sep. 13, 2019, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also a continuation-in-part of U.S. Non-Provisional Application No. 17/676,949, filed Feb. 22, 2022, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” which is a divisional of U.S. Non-Provisional Application No. 17/519,827, filed Nov. 5, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,415,056, issued Aug. 16, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/502,120, filed Oct. 15, 2021, titled “METHODS FOR NOISE DAMPENING AND ATTENUATION OF TURBINE ENGINE,” now U.S. Pat. No. 11,560,848, issued Jan. 24, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/498,916, filed Oct. 12, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,459,954, issued Oct. 4, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/182,325, filed Feb. 23, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,242,802, issued Feb. 8, 2022, which is a continuation of U.S. Non-Provisional Application No. 16/948,290, filed Sep. 11, 2020, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 10,961,914, issued Mar. 30, 2021, which claims priority to and the benefit of, U.S. Provisional Application No. 62/704,567, filed May 15, 2020, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM FOR NOISE DAMPENING AND ATTENUATION,” and U.S. Provisional Application No. 62/899,957, filed Sep. 13, 2019, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM FOR NOISE DAMPENING AND ATTENUATION,” the disclosures of which are incorporated herein by reference in their entireties.
This is also a continuation-in-part of U.S. Non-Provisional Application No. 18/108,821, filed Feb. 13, 2023, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” which is a continuation of U.S. Non-Provisional Application No. 17/585,766, filed Jan. 27, 2022, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” which is a continuation of U.S. Non-Provisional Application No. 17/469,970, filed Sep. 9, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,280,331, issued Mar. 22, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/363,151, filed Jun. 30, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,149,726, issued Oct. 19, 2021, which is a continuation of U.S. Non-Provisional Application No. 17/213,562, filed Mar. 26, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,092,152, issued Aug. 17, 2021, which is a continuation of U.S. Non-Provisional Application No. 16/948,291, filed Sep. 11, 2020, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,015,594, issued May 25, 2021, which claims priority to and the benefit of U.S. Provisional Application No. 62/704,560, filed May 15, 2020, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” and U.S. Provisional Application No. 62/899,963, filed Sep. 13, 2019, titled “USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER SYSTEM FOR SINGLE ACTING RECIPROCATING PUMP,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also a continuation-in-part of U.S. Non-Provisional Application No. 18/116,383, filed Mar. 2, 2023, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/976,095, filed Oct. 28, 2022, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/555,815, filed Dec. 20, 2021, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S Pat. No. 11,530,602, issued Dec. 20, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/203,002, filed Mar. 16, 2021, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,236,739, issued Feb. 1, 2022, which is a divisional of U.S. Non-Provisional Application No. 16/946,079, filed Jun. 5, 2020, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,989,180, issued Apr. 27, 2021, which claims the benefit of and priority to U.S. Provisional Pat. Application No. 62/899,971, filed Sep. 13, 2019, titled “AUXILIARY DRIVE SYSTEMS AND ALTERNATIVE POWER SOURCES,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also continuation-in-part of U.S. Non-Provisional Application No. 18/147,880, filed Dec. 29, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/936,885, filed Sep. 30, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,578,660, issued Feb. 14, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/883,693, filed Aug. 9, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,512,642, issued Nov. 29, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/808,792, filed Jun. 24, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,473,503, issued Oct. 18, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/720,390, filed Apr. 14, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,401,865, issued Aug. 2, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/671,734, filed Feb. 15, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,346,280, issued May 31, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/204,338, filed Mar. 17, 2021, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,319,878, issued May 3, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/154,601, filed Jan. 21, 2021, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,982,596, issued Apr. 20, 2021, which is a divisional of U.S. Non-Provisional Application No. 17/122,433, filed Dec. 15, 2020, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,961,912, issued Mar. 30, 2021, which is a divisional of U.S. Non-Provisional Application No. 15/929,924, filed May 29, 2020, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,895,202, issued Jan. 19, 2021, which claims the benefit of and priority to U.S. Provisional Application No. 62/899,975, filed Sep. 13, 2019, titled “TURBINE REMOVAL SYSTEM,” the disclosures of which are incorporated herein by reference in their entireties.
BACKGROUNDThis disclosure generally relates to hydraulic fracturing. More particularly, this disclosure relates to systems for performing hydraulic fracturing that include one or more hydraulic fracturing units (or pumping units).
Hydraulic fracturing is an oilfield operation that stimulates production of hydrocarbons, such that the hydrocarbons may more easily or readily flow from a subsurface formation to a well. For example, a hydraulic fracturing system may be configured to fracture a formation by pumping a fracturing or fracking fluid into a well at high pressure and high flow rates. Some fracturing fluids may take the form of a slurry including water, proppants (e.g., sand), and/or other additives, such as thickening agents and/or gels. The slurry may be forced via one or more pumps into the formation at rates faster than can be accepted by the existing pores, fractures, faults, or other spaces within the formation. As a result, pressure builds rapidly to the point where the formation fails and begins to fracture.
By continuing to pump the fracturing fluid into the formation, existing fractures in the formation are caused to expand and extend in directions farther away from a well bore, thereby creating flow paths to the well bore. The proppants may serve to prevent the expanded fractures from closing when pumping of the fracking fluid is ceased or may reduce the extent to which the expanded fractures contract when pumping of the fracturing fluid is ceased. Once the formation is fractured, large quantities of the injected fracturing fluid are allowed to flow out of the well, and the production stream of hydrocarbons may be obtained from the formation.
The one or more pumps may be arranged in a plurality of hydraulic fracturing units positioned at the fracturing operation site. Each hydraulic fracturing unit may include at least one of the one more pumps and a prime mover. In addition, each hydraulic fracturing unit may be mobilized on, for example, a skid or a tractor-trailer.
Hydraulic fracturing has been utilized in a great number of wells to enhance, initiate, or reinitiate production of oil, gas, or other formation fluids. As a result, hydraulic fracturing operations have steadily been improved. However, there remains an ever-present need for further improvements to a hydraulic fracturing operation to enhance performance and efficiency.
BRIEF SUMMARYSome embodiments disclosed herein are directed to a pumping unit. In some embodiments, the pumping unit includes a gas turbine engine, an enclosure housing the gas turbine engine, an exhaust assembly connected to the gas turbine engine, an air intake duct connected to the gas turbine engine, and an air treatment system connected to the air intake duct. The air treatment system comprising one or more inlet pre-cleaners configured to eject debris. Each of the one or more inlet pre-cleaners having a cylindrical tubular portion configured to channel air toward the air intake duct. In addition, the pumping unit includes a gearbox operatively coupled to the gas turbine engine. Further, the pumping unit includes a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox. Still further, the pumping unit includes a pump comprising an input shaft operatively coupled to the second end of the drive shaft, wherein the gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pumping unit.
In some embodiments, the pumping unit includes a chassis and an enclosure disposed on the chassis. The enclosure houses a gas turbine engine and a gearbox operatively coupled to the gas turbine engine. The enclosure includes a first lateral side, a second lateral side, and a door mounted on the first lateral side proximate to the gas turbine engine. In addition, the pumping unit includes an exhaust assembly connected to the gas turbine engine, an air intake duct connected to the gas turbine engine, and an air treatment system connected to the air intake duct, the air treatment system comprising one or more inlet pre-cleaners configured to eject debris particles via inertia of the debris particles. Further, the pumping unit includes a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox. Still further, the pumping unit includes a pump disposed on the chassis, the pump comprising an input shaft operatively coupled to the second end of the drive shaft, wherein the gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pumping unit.
Some embodiments disclosed herein are directed to a hydraulic fracturing system. In some embodiments, the hydraulic fracturing system includes a plurality of hydraulic fracturing units and a fuel line configured to supply fuel from a fuel source to the plurality of hydraulic fracturing units. A first hydraulic fracturing unit of the plurality of hydraulic fracturing units includes a gas turbine engine, an enclosure housing the gas turbine engine, an exhaust assembly connected to the gas turbine engine, an air intake duct connected to the gas turbine engine, an air treatment system connected to the air intake duct, the air treatment system comprising one or more inlet pre-cleaners configured to eject debris, a gearbox operatively coupled to the gas turbine engine, and a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox. In addition, the first hydraulic fracturing unit incudes a pump comprising an input shaft operatively coupled to the second end of the drive shaft. The gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pump, and a longitudinal axis of the drive shaft is offset from a longitudinal axis of the input shaft of the pump.
Embodiments described herein comprise a combination of features and characteristics intended to address various shortcomings associated with certain prior devices, systems, and methods. The foregoing has outlined rather broadly the features and technical characteristics of the disclosed embodiments in order that the detailed description that follows may be better understood. The various characteristics and features described above, as well as others, will be readily apparent to those having ordinary skill in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated that this disclosure may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes as the disclosed embodiments. It should also be realized that such equivalent constructions do not depart from the spirit and scope of the principles disclosed herein.
For a detailed description of various embodiments, reference will now be made to the accompanying drawings in which:
As previously described, there is a continuing need for further improvements to a hydraulic fracturing operation to enhance performance and efficiency. In some circumstances, a gas turbine engine may be used to power the pump(s) of the hydraulic fracturing unit during a hydraulic fracturing operation. Gas turbine engines carry a number of advantages, including (for instance) a generally smaller size and higher power to weight ratio than a traditional diesel engine. However, the use of gas turbine engines to power the one or more pumps for a hydraulic fracturing operation also includes a unique set of challenges. For instance, a hydraulic fracturing system (and particularly one that employs gas turbine engines) may face challenges relating to power distribution, spacing (and footprint management), operational noise, vibration management (e.g., within the hydraulic fracturing units), operation of the gas turbine engines in a range of environmental conditions, etc.
Accordingly, the embodiments disclosed herein provide systems and methods for addressing many of the challenges associated with performing a hydraulic fracturing operation, including some challenges that are associated with the use of gas turbine engines to power the one or more pumps of the hydraulic fracturing system.
While a number of embodiments of systems and methods are described herein, it should be appreciated that other embodiments are contemplated that utilize a combination (including a subset) of features of one or more (or all) of the various embodiments that are particularly described. Thus, the description of the various embodiments should not be interpreted as limiting the particular combinations or sub-combinations of features that may be utilized in other embodiments according to this disclosure. Moreover, at least some of the embodiments disclosed herein may also be relevant to hydraulic fracturing system that utilize prime movers that are not gas turbine engines (such as diesel engines, electric motors, etc.). Thus, unless otherwise specified, the embodiments disclosed herein may be employed to improve the operations of hydraulic fracturing systems that do and that do not employ gas turbine engines.
Some embodiments disclosed herein include electric power arrangements for a hydraulic fracturing system that are to deliver power (such as electrical power) to one or more components thereof. For instance, hydraulic fracturing units (including those that employ gas turbine engines, or other prime movers such as diesel engines or electric motors) have onboard auxiliary equipment that is operated in conjunction with the powertrain to ensure that equipment is lubricated and protected, and also to enhance to efficiency of the equipment. Examples of these onboard auxiliary equipment include lubrication pumps that provide low-pressure and high-pressure gear oil injection into the reciprocating pump crank case and bearing housings. The injection of this oil into the pump’s power end ensures that friction between mating surfaces is reduced, and it also mitigates the heat rejection from this friction and prevents it from elevating to a temperature that may cause wear and premature failure.
Cooling equipment is another example of auxiliary equipment onboard many hydraulic fracturing units. The cooling equipment includes multiple cooling circuits for engine cooling, transmission cooling, pump lube oil cooling, hydraulic cooling and the like. This cooling equipment may include tube and shell heat exchangers, but it is more common to utilize fan-driven heat exchangers that allow for the control of fan speed that permits operators to mitigate the amount of cooling performed and conserve energy used to drive fan motors.
The auxiliary equipment needs driving power to allow the equipment to perform respective functions and operate efficiently. Thus, some embodiments disclosed herein include hydraulic fracturing systems that include one or more electric power arrangements configured to power the auxiliary equipment of the hydraulic fracturing units. As will be described in more detail below, each electric power arrangement may include an engine-generator set configured to generate electric power, and an electric power network coupled to the engine-generator set and the electric motors. The electric power network may also be coupled to a utility power grid, a battery bank or a second engine-generator set of a neighboring hydraulic fracturing unit. The electric power network may be configured to deliver the electric power generated by the engine-generator set to one or more electric motors to drive the auxiliary equipment. In addition, the electric power network may be configured to switchably connect the utility power grid, the battery bank or the second engine-generator set to deliver power to the electric motors responsive to a failure or fault of the engine-generator set.
More particularly, in the system 100 shown in
The hydraulic fracturing units 102 take the fracturing fluid and discharge it at high pressure through individual high-pressure “discharge” lines into two or more high-pressure lines or “missiles” on the manifold 104. The missiles flow together, such that they are manifolded on the manifold. Several high-pressure flow lines run from the manifolded missiles to a “goat head” that delivers the fracturing fluid into a “zipper” manifold. The zipper manifold allows the fracturing fluid to be selectively diverted to, for example, one of two well heads. Once fracturing is complete, flow back from the fracturing operation discharges into a flowback manifold which leads into flowback tanks.
Because systems for fracturing a well are required on site for a relatively short period of time, the larger components of the system 100 typically are transported to a well site on skids, trailers, or trucks as more or less self-contained units. As used herein, the term “trailer” refers to any transportation assembly, including, but not limited to, a transport, truck, skid, and/or barge used to transport relatively heavy structures, such as fracturing equipment. Once the components of the system 100 arrive at the well site, they are then connected to the system by one kind of conduit or another. In
The pump 126 may be reciprocating plunger pump including a power end and a fluid end. The power end transforms rotational motion and energy from a powertrain 128 into the reciprocating motion that drives plungers in the fluid end. In the fluid end, the plungers force fluid into a pressure chamber that is used to create high pressure for well servicing. The fluid end may also include a discharge valve assembly and a suction valve assembly.
The hydraulic fracturing unit 102 includes the powertrain 128 also connected to the chassis 124 and configured to power the pump 126. In this regard, the powertrain includes a prime mover 130 and a drivetrain 132. In some examples, the hydraulic fracturing unit is a direct drive turbine (DDT) unit in which the prime mover 130 is or includes a gas turbine engine (GTE) 134. As also shown, the drivetrain 132 includes a reduction transmission 136 (such as a gearbox) connected to a drive shaft 138, which, in turn, is connected to the pump such as via an input shaft or input flange of the pump. Other types of GTE-to-pump arrangements are contemplated.
In some examples, the GTE 134 may be a direct drive GTE. The GTE may be a dual-fuel or bi-fuel GTE, for example, operable using of two or more different types of fuel, such as natural gas and diesel fuel, although other types of fuel are contemplated. For example, a dual-fuel or bi-fuel GTE may be capable of being operated using a first type of fuel, a second type of fuel, and/or a combination of the first type of fuel and the second type of fuel. For example, the fuel may include compressed natural gas (CNG), natural gas, field gas, pipeline gas, methane, propane, butane, and/or liquid fuels, such as, for example, diesel fuel (e.g., #2 Diesel), bio-diesel fuel, bio-fuel, alcohol, gasoline, gasohol, aviation fuel, etc. Gaseous fuels may be supplied by CNG bulk vessels, a gas compressor, a liquid natural gas vaporizer, line gas, and/or well-gas produced natural gas. Other types and sources of fuel are contemplated. The GTE may be operated to provide horsepower to drive the pump 126 via the drivetrain 132 to safely and successfully fracture a formation during a well stimulation project.
As also shown, the hydraulic fracturing unit 102 includes auxiliary equipment 120 located onboard the chassis 124 and configured to support operation of the hydraulic fracturing unit including the pump 126 and the powertrain 128. As described above, the auxiliary equipment onboard the hydraulic fracturing unit may include lubrication and cooling equipment such as cooling fans and lubrication pumps. More particular examples of auxiliary equipment include a lube oil pump coupled to the reduction transmission 136, a cooling fan coupled to a reduction transmission lube oil pump, a lube oil pump coupled to the power end of the pump, a cooling fan coupled to a power end lube oil pump, a cooling fan to the GTE 134, a GTE air cooling fan, a screw type air compressor, an air dryer, greaser equipment for the pump 126, an air intake blower fan motor, a GTE controller, a hydraulic starter pump, a GTE lube cooling fan, a telescope exhaust winch, a master programmable logic controller (PLC), and the like.
As shown in
As shown, the power arrangement 140 generally includes a power source 142 and a power network 144. The power source 142 is configured to generate power for the auxiliary equipment 120. The power network 144 is coupled to the power source 142 and the auxiliary equipment 120 and configured to deliver the power generated by the power source 142 to the auxiliary equipment 120.
In various examples, the power arrangement 140 may be an electric power arrangement or a hydraulic power arrangement.
As shown in
One particular example of a suitable GTE 162 that could be made part of the electric power source 152 is a microturbine from Capstone Turbine Corporation, although other turbines with similar technology and compact foot print could also be used. Gas turbine engines such as Capstone microturbines can be installed individually or in a parallel multipack configuration to create a local power grid that can be quiet, lightweight, modular and have low maintenance. Capstone microturbines and others like them have similar fuel capabilities to that of the Vericor TF50F turbine engine in such a way that even though natural gas is their preferred fuel source, diesel can be introduced as fuel for the turbine for a short period of time making this turbine adaptable to operating conditions and fuel shortage scenarios.
The utilization of a microturbine as the GTE 162 in the electric power source 152 may result in lower emissions to that of a reciprocating engine such as a diesel engine. This may allow for a single fuel hook up for CNG, reduce total operating costs, and reduce the power generation package size on the hydraulic fracturing unit 102. Other machinery and components associated with the main turbine air intake conditioning such as chillers and filters may also be shared with this microturbine.
In some examples, the electric power arrangement 150 further includes a connection 166 to shore power from an external source of electric power, such as a utility power grid, another engine-generator set or the like, from which the auxiliary equipment 120 are also powerable. Additionally or alternatively, in some examples, the electric power arrangement further includes a battery bank 168 chargeable from the power generated by the electric motor generator 164, and from which the auxiliary equipment are also powerable. The battery bank may include one or more batteries such as lithium on or lead acid batteries. In some examples in which the power arrangement 140 is onboard the hydraulic fracturing unit 102, and the hydraulic fracturing units of the system 100 include respective power arrangements, the electric power arrangement further includes a connection 170 to a second power arrangement of a neighboring hydraulic fracturing unit from which the auxiliary equipment are also powerable.
The auxiliary equipment 120 may be powered from the engine-generator set 158, the shore power from the external source of electric power, the second electric power arrangement from a neighboring hydraulic fracturing unit 102, or the battery bank 168. In some examples, the electric power network 154 is configured to deliver the electric power generated by the engine-generator set to the electric motors 156 to drive the auxiliary equipment. In some of these examples in which the engine-generator set experiences a fault or failure, the electric power network may then, in response, switchably connect the utility power grid, the battery bank or the second engine-generator set to deliver power to the electric motors.
As indicated above, the power arrangement 140 the power arrangement may be located onboard the hydraulic fracturing unit 102.
As shown in
In some examples, the plurality of hydraulic fracturing units 220 include neighboring hydraulic fracturing units, and the respective power arrangements 140 of the neighboring hydraulic fracturing units are connected to one another, and from which the respective auxiliary equipment 120 of the neighboring hydraulic fracturing units are also powerable. This is shown by power cables 232 between neighboring hydraulic fracturing units in
In the event power is lost on a hydraulic fracturing unit 220 equipped with a respective power arrangement 140, an automatic switching mechanism may allow neighboring hydraulic fracturing units joined by a receptacle and plug to share power. The neighboring hydraulic fracturing unit, then, may be able to provide power to the hydraulic fracturing unit allowing its auxiliary equipment. If for some reason both hydraulic fracturing units wanted to operate at the same time and distribute both of their power to a third hydraulic fracturing unit, the inclusion of synchronizing components such as a synchro scope may ensure the speed and frequency of their power arrangements are the same.
As shown in
In
In other example implementations, the system may include the power arrangement configured to power the auxiliary equipment across the plurality of hydraulic fracturing units 102 if not also backside equipment such as the chemical unit 108, hydration unit 110, conveyors 112, sand tanks 114, blender 116, data center 118 and the like.
Due to high amperage draw from hydraulic fracturing units 102, single power cables carrying the necessary voltage from the power arrangement 140 to the hydraulic fracturing units 102 may not be suitable due to this amperage rating being unachievable. Each hydraulic fracturing unit 102 that relies on the power arrangement to power its auxiliary equipment 120 may have a divided bus to allow the total amperage to the hydraulic fracturing unit to be halved over an aluminum or copper bus bar allowing a single power cable to power each bus. Some backside equipment such as the chemical unit 108 and data center 118 may not require high continuous power and can be equipped with a single power distribution such as a bus bar.
In
As shown in
To further illustrate example implementations of the present disclosure,
The diesel engine 292 may be operatively coupled to the electric generator 294 to supply electrical power to multiple electric drivers that power one or more auxiliary equipment such as cooling fans and lube oil pumps. Examples of a suitable electric generator include a Caterpillar Model SR4 200 KW, a Kato 200 KW Model A250180000, and the like. In some examples, the electric generator 294 may be configured to provide 230/240-volt, 3-phase power or 460/480-volt, 3-phase power to individual variable frequency drives (VFDs) 1504 to power various motors 1506 of the auxiliary equipment.
The VFD 274 may include a full wave three-phase rectifier configured to convert incoming three-phase AC voltage to a desired DC voltage through a plurality (e.g., 9) of silicon controlled rectifiers (SCRs) or diodes. This DC voltage may then power those of the motors 276 that are DC motors. Alternatively, the generated electrical current may be sent through an inverter at the prescribed voltage and synthesized sine wave frequency such that the VFDs may selectively control the operation of AC motors. This may be by the providing prescribed voltage and synthesized sine wave frequency the VFD selectively controls the speed and direction of the AC motors. In some examples, the VFDs 274 may be configured to directly supply AC power to the AC motors 276, thereby eliminating the use on an external inverter. One example of a suitable VFD with connections to an AC motor is depicted in
The VFDs 274 may power the motors 276 of various auxiliary equipment 290, the operation of each of which may add a load onto the electric power arrangement 275. Examples of various auxiliary equipment and respective approximate loads include:
- lube oil pump to the gearbox (1 HP)
- cooling fan to gearbox lube oil pump (15 HP)
- lube oil pump to the power end (15 HP)
- cooling fan to the power end lube oil pump x 2 (15 HP each)
- cooling fan to the CAT C9 engine (10 HP)
- CAT C9 engine air cooling fan (10 HP)
- screw type air compressor to provide 150 pounds per square inch (PSI) air for fuel equipment intensifier to amplify to > 200 PSI (7.5 HP) with air dryer (0.75 HP)
- greaser equipment for the fracturing pump (0.25 HP)
- air intake blower fan motors x 2 (40 HP each)
- GTE controller (1 HP)
- hydraulic starter pump equipment (60 HP)
- turbine lube cooling fan (4 HP)
- telescope exhaust winch x 2 (1 HP each)
- master PLC for VFD / electric generator (2 HP)
- Total 236.5 HP / 176 kW
As suggested above, in some examples, the electric power arrangement 275 may be more efficient with finer control of cooling and lubrication through feedback loops continuously monitored by processing circuitry such as a programmable logic controller (PLC). Examples of suitable controllers include a Parker IQANTM controller, a Danfoss Plus+One® controller, or a custom process controller.
In some examples, the electric power arrangement 275 may also be powered by shore power 296 through a separate connection to an external source of electric power. If using shore power, a selectable switch may be configured to selectably separate the electric generator 294 from the shore power 296. In some examples, the electric power arrangement 275 may include or be connected to a battery bank 298 that may supply power in the case of diesel engine failure or shore power failure.
Further consider examples of the system 250 in
- hydraulic fracturing units (x7) = 1655.5 HP
- chemical unit = 107 HP
- hydration unit = 665 HP
- sand tanks = 750 HP
- blender = 1433 HP
- data center = 500 HP
The module hydraulic pump drive 314 may power auxiliary equipment 320 though motors and hydraulic pumps 322, which may be coupled to the module hydraulic pump drive individually or in tandem. In this regard, the hydraulic pumps may be configured to supply hydraulic fluid to corresponding hydraulic motors of various auxiliary equipment. These again may power auxiliary equipment such as cooling fans and lube oil pumps. Examples of various auxiliary equipment and respective approximate loads include:
- lube oil pump to the gearbox (1 HP)
- cooling fan to gearbox lube oil pump (8 HP)
- lube oil pump to the power end low pressure (11 HP)
- lube oil pump to the power end high pressure (18 HP)
- cooling fan to the power end lube oil pump (40 HP)
- greaser equipment for the fracturing pump (1 HP)
- Turbine Fuel Pump (1.5 HP)
- Turbine Washing System (1 HP)
- Turbine/Gearbox/Hydraulic Cooler Fan (40 HP)
- Air exchange Fans (10 HP)
- Hydraulic Pump for Turbine Starter, Lid openings, Compressor etc (70 HP)
- Total 201 HP / 150.37 kW
This hydraulic power arrangement 300 does not rely on a diesel engine but instead an electric motor that may operate off shore power from an external source of electric power that may supply power to multiple units on a jobsite, thereby eliminating at least several components that may be required for a diesel engine (e.g., a fuel pump, an air compressor, an engine cooling fan).
In some examples, the alternator 336 may be engaged with or disengaged from the PTO 334 via a hydraulic or pneumatic clutch to allow the GTE 344 to direct more power through the drivetrain and into the pump if needed. When disengaged from the PTO, the auxiliary equipment may be powered from shore power connections and other generated grid power. When the alternator is engaged with the PTO 334, as well as feeding auxiliary equipment such as cooling fans and compressors, an uninterrupted power source (UPS) 338 may be constantly charged during pumping operations. This UPS 338 may be used to solely drive a hydraulic pump that will be used to start the GTE by feeding hydraulic power to the motor starter.
An active front end (AFE) 340 may be placed on the two outputs of the alternator 336 to change AC voltage to DC.
As described above and reiterated below with further example implementation details, various example implementations are disclosed herein that provide power arrangements and methods for powering of auxiliary equipment onboard a hydraulic fracturing unit such as a DDT hydraulic fracturing unit or trailer. The auxiliary equipment include, for example, cooling of process fluids through heat exchangers, pumping equipment, compressor units, winches and linear actuators, electrical control equipment, heats/coolers and hydraulic equipment. The power arrangements of example implementations may be configurable and may be adjusted to suit the needs of each individual scenario and situation.
Some example implementations of a power arrangement include an engine or prime mover onboard the gooseneck area of a GTE-driven hydraulic fracturing unit. The engine / prime mover may be connected to an electric power generator such as a PM motor or a hydraulic pump drive with one or more pumps.
Some example implementations include a diesel reciprocating engine onboard the GTE-driven hydraulic fracturing unit, and other example implementations includes an electric motor in place of the diesel engine. The location of the engine / motor may be the gooseneck area of a trailer, but the design of the trailer may permit installation of the engine / motor on the rear axles of the trailer.
In examples including the diesel engine, it may be equipped with supporting equipment such as fuel reservoirs, coolant reservoirs, battery banks, diesel exhaust fluid tanks and cooling fans. The cooling fan on the diesel engine may be supplied by the engine manufacturer and mounted from a PTO located on the engine or it may be made external and powered from the hydraulic power network coming from the hydraulic pump drive. In another implementation, the diesel engine may be replaced with an electric motor that when installed is accompanied by electric switch gear that houses overload protection as well as a form of isolating the electric motor. Directly mounted from the diesel engine may be the hydraulic pump drive, which may be connected to the electric motor in another implementation.
The hydraulic pump drive may have a female spur shaft connection that is installed onto the diesel engine or electric motor, and the two components may be secured via a bell housing that connects a face of the engine/motor to a face of the hydraulic pump drive. Once installed the hydraulic pump drive may be configured to house up to four pumps but will be rated by the total amount of horse power and torque it may yield at each output gear. Depending on the application, the use of a large displacement single pump directly coupled to the diesel engine may be beneficial. But there may be equal portion of components over the trailer that are operating at different pressures, such as a compressor and fans that operate at a flow that will generate 2000 PSI, and the pumps may operate at 3000 PSI at rated flow. Therefore, a variable displacement hydraulic pump with a compensator setting of 2000 PSI, and another pump with a compensator setting of 3000 PSI, may meet pressure requirements of each circuit bearing in mind that the output flow rate of each pumps should meet the flow demand from all components.
Depending on the configuration of pumps there may be multiple hydraulic reservoirs installed on the hydraulic fracturing unit that would allow for each individual pump installed on the hydraulic pump drive to draw fluid from. This may mean that a pump with a greater suction vacuum would not take away fluid from a pump with a small displacement therefore a smaller suction pressure. Alternatively pump suction lines may be positioned in a way this does not happen, but the size of the reservoir and mounting location of the reservoir dictate this. The space taken up by the hydraulic reservoir may depend on flow demand within the auxiliary equipment. The dwell time for fluid may be greater in the individual or group of reservoirs due to the hydraulic power network being open circuit, meaning that the displaced fluid from the pump may go to the desired component and then return to tank opposed to returning to the pumps suction side.
The hydraulic power network coming from the hydraulic pump drive may be equipped with filtration in the form of single or double housings that ensure fluid cleanliness is maintained to the best industry standard that is usually dictated by the International Organization for Standardization (ISO) fluid cleanliness classification.
A diesel engine directly coupled to a hydraulic pump drive that is installed with hydraulic pumps may allow for great versatility. The adjustment of pump pressure and flow settings may allow the pumps to operate at their maximum efficiency while still ensuring they meet the power demands of the auxiliary equipment.
Working in conjunction with the hydraulic pumps may be hydraulic directional control valves that isolate fluid going to individual circuits, and when actuated, allow a valve spool to shift and direct flow through the ports. In the case of hydraulic motors driving fluid pumps and fans, these components may be controlled to operate in a single direction to avoid damage to pumps and mis-operation of fans. This may be done by selecting a directional control valve with a closed center and two positions.
In a de-energized state there may be no flow through the valve, resulting in the pump swash plate to move to the neutral position and stop displacing fluid. When operated via an electric signal energizing the solenoid from an electric control system, or commonly referred to as a supervisory control system (SCS), flow may be allowed to pass through the control valve to the designated auxiliary equipment that may operate a hydraulic motor. Return fluid may also be plumbed back to the hydraulic control valve and passed to a return line where it may be diverted back to the hydraulic reservoir. The control valves may be installed in multiple valves assemblies, commonly referred to as a “valve bank.”
Another part of the hydraulic power arrangement may be cooling circuits. The operation of hydraulic power networks may generate heat as the fluid flowing through different orifices, and the resulting pressure drop yields heat into the fluid that may not only degrade fluid lubrication properties but also cause problems to the components being operated with the fluid. To mitigate this, hydraulic cooling circuits may be installed that are activated by thermostatic control valves. When the fluid gets too hot, the valve may open and diverts fluid though a fan driven heat exchanger ensuring that it’s cooled prior to returning to the reservoir and being introduced back into the hydraulic power network.
The diesel engine and hydraulic package may be configured to easily fit onto the gooseneck of a standard hydraulic fracturing unit while still ensuring space for additional components such as reservoirs, heat exchangers and compressors. Hydraulic pumps installed from the hydraulic pump drive or directly from the engine are often very versatile. Ensuring that the flow requirements may be met, the pumps pressure compensator setting, as well as the introduction of load sensing, may ensure that only the required amount of power is drawn from the hydraulic pump. This may mean that the engine is operated at the power required, and that wasted energy and fuel is eradicated, thereby improving efficiency.
The complexity of an individual hydraulic power network is not high, and the introduction of a hydraulic pump drive with multiple individual network branches may still maintain a simple approach without the need to interface all pumps into a single common pressure line. The versatility of adding hydraulic pump drives with different output gears while still maintaining the same circuitry in place may be a benefit of a driven hydraulic network branch and allow for expansion in circuitry without the need to perform complex adjustments.
Operation of a circuit during hydraulic fracturing may be as follows. The SCS may operate from a battery storage device, which may be charged from an alternator or shore power provided to the implementation inclusive of an electric motor driving the hydraulic power network. The SCS may interface with the diesel engine through the engines electric control module (ECM), and from this, the engine may be given start, stop or throttle commands. Engine equipment information may also be sent through J1939 communication protocol.
During startup of the hydraulic fracturing unit, the diesel engine may be sent a start command and reach idle speed; or in another example implementation, electric power brought onboard may enter a VFD. The SCS may send a digital output to the drive to start up. In addition to that digital signal, an analog signal in the state of 4-20 mA or 0-10 V may be used to control the speed. The SCS may command the prime mover on the diesel engine to then go to a run speed which is typically 1900 RPM for most systems but could be as high as 2100 or as low as 1700 RPM. This speed may allow the hydraulic power source to operate at maximum power output and begin supplying flow into the hydraulic power network. The directional control valves may then be operated in a sequence ensuring that all pre-conditions are met before bringing the turbine engine online.
When the fuel and lubrication pumps are operating within the correct parameters, the GTE start motor may be operated. This axial motor may be installed on a gearbox or other transmission toward a cold end of the turbine engine, and it may receive hydraulic flow. When the GTE reaches an idle speed, a sprag clutch in the turbine starter motor assembly may disengage, allowing combustion within the turbine combustion chamber to maintain the turbine speed. Upon reaching the idle speed, a signal may be removed from the hydraulic control valves to halt fluid to the starter motor. The hydraulic power arrangement may then operate the turbine engine and pump auxiliary equipment to distribute hydraulic flow through the control valves as per logic programmed into the SCS. As with startup of the diesel engine or operation of the electric motor, the SCS may be responsible for sending shutdown signals to either the diesel engine’s ECM or electric motor frequency drive.
In other example implementations, the hydraulic power arrangement may be replaced with an electric motor such as a PM motor that is directly coupled to the engine output shaft and connected to the engine housing via a bell housing adapter. However, a splined coupling may interface the two shafts, and a coupling may connect these splined adapters together. The PM motor may operate at an optimal speed of 1900 RPM to generate 500 VAC power. At this speed and power generation, an electric generator may yield a power factor of 0.93 making the generator highly efficient.
The electric generator may also include a cooling circuit that is operable between 5-10 gallons per minute (GPM) and acts as a heat exchanger through the generator ensuring that the temperature on the generator winding does not exceed 175° C. A small pump to circulate this fluid may be first driven from battery storage device until the electric generator comes online and begins to re-charge the battery storage device and then power its own cooling pump.
Coming from the generator may be the electric conditioning station that may also be located on the gooseneck in a water and dust proof IP66 enclosure. A cable carrying three-phase power may enter the enclosure into a main isolation breaker with overload protection, and from this, the power cable may be run into an AFE drive that may condition the signal into a DC voltage. Control of this AFE may be through the SCS, and communication may be carried out via modbus protocol. Downstream of the AFE may be a main DC bus bar that may hold the electric potential to distribute power to each individual control circuit around the hydraulic fracturing unit.
From the bus bar there may be an individual circuit protection breaker for each control circuit that may be equipped with overload protection. In the event the current drawn from the motor in the control circuit is too great, the overload protection may trip the breaker resulting in power loss to that circuit and protection of all components in that circuit. From these individual circuit breakers, armored and shielded cables may then leave the enclosure through bulkhead connections equipped with explosion proof glands and assembly methods that ensure the integrity of the main switch gear assembly may be protected from potentially combustible gases. The cables may be secured in a cable tray that may then run to areas in which the electric motors may be in place.
Prior to terminating the electric supply cables to the motor, the cables may first be terminated to an inverter drive that may convert the DC voltage into an AC voltage. The benefit of this may be the ease of sourcing AC electric motors and their lower capital costs. The inverter may condition the power coming in and leaving the drive. The inverter may also allow for proportional speed control of the motor and soft start functioning of the motor to reduce a current rush into the motor potentially tripping any circuit overload protection in the drive or back at the main isolator coming from the common bus bar.
The electric motors connected to the electric drives may be used in place of hydraulic motors as detailed in other example implementation but may still be fluidly connected to the driven equipment such as pumps, fans, compressors with the use of couplings and bell housing adapters. Other driven equipment may be driven with the use of electric motors and are contemplated herein.
A method of operation of the power arrangement of some examples may be as follows. The engine may be brought online in a similar manor to the previously described implementation in which the SCS may send a start signal to the diesel engine ECM via J1939 communication protocol. The engine may be brought online to a speed of 1900 RPM, at which point the electric generator may be producing 500 VAC electric power with the electric potential of up to 223 KW.
The alternating current power form the electric generator may enter the electric conditioning assembly including the main isolator and the AFE rectifier that may convert the power to DC and distribute it over the electric bus bar. Current may be then able to flow into the main isolator for each electric circuit. The current may then flow around the hydraulic fracturing unit via the correctly sizes armor shielded electric cable into the inverter drive. The inverters may be networked and communicated with from the SCS. The SCS may function the inverter drive and alter the frequency in which the IBGTs of the AFE sequence, which may result in the frequency leaving the drive to the motor to be controlled, and thereby controlling the speed of which the motors turns.
The power arrangement of these example implementations may allow for very accurate control of the individual circuitry. The analog signals to the drives may ensure that the frequency provided to the electric motors allows for exact RPMs to be met within 5-10 RPM tolerance. Electric motors may also provide a robust option for driving pumps and other auxiliary equipment. The lack of potential fluid contamination or fluid degradation usually allows these motors to stay in service longer ensuring that load bearings are greased and correct mounting of the motor may be performed. This implementation to drive auxiliary equipment of the hydraulic fracturing unit with electric motors may also provide benefit from lack of fluid travelling the entirety of the hydraulic fracturing unit, which may be susceptible to pressure drops and leaks.
As previously mentioned, the ability to share generated power may be a benefit of the diesel engine and generator set up. For example, if ten hydraulic fracturing units are on location, and each generator produces more power than may be required on the individual hydraulic fracturing unit, a shared power configuration could see a portion of the ten hydraulic fracturing unit gen-sets taken offline and the remainder of the hydraulic fracturing units providing all hydraulic fracturing units with the total amount of electric energy required.
Another example implementation of a method to power auxiliary equipment onboard hydraulic fracturing units may utilize the GTE transmission and include PTOs on the transmission to power a smaller electric generator and a single multistage pump. In some of these examples, a transmission such as a gearbox with a single input and output shaft may be modified to account for two additional PTOs positioned either side of the main output shaft or flange. These PTOs may be equipped with clutches that may be operated either pneumatically or hydraulically (or electrically in other example implementations).
As well as the installation of the transmission with the PTOs, additional equipment may be installed onto the GTE-driven hydraulic fracturing unit to ensure that a controlled startup may be performed to get to a point where it may be self-sustained from its own operation. Taking this into account, a battery bank with one or more high-powered lithium-ion batteries may be used to provide the starting power for onboard auxiliary equipment such as lube and fuel pumps as well as powering the electric motor that may be coupled to the GTE starter gear. Once the GTE is at running speed and there is motion at the output shaft, the clutches may be engaged to allow for the pumps and electric generator to receive torque and motion from the transmission and start to displace fluid and generate power.
A single pump may address the needs of the reciprocating fracturing pump, and the single pump be a multistage pump that allows fluid to enter both low and high pressure sides of the pump. In other example implementations, the electric generator installed onto the diesel engine may supply enough power to all of the onboard auxiliary equipment. This may be not feasible when using a PTO from the transmission due to the footprint available and the large cantilever loading from the transmission as it may already support the mass of the GTE. Therefore, by taking away the reciprocating pump lube power requirements from the total KW load, there may or may not be use of a smaller generator capable of driving small motors coupled to fans that could range from 1 to 5 HP, as well as low pressure low flow fuel pumps and transmission lube pumps.
As in other implementations, the SCS may be powered from a separate battery bank but may still allow for generated power to replenish the battery charge when operational. The remaining auxiliary equipment to be powered from the smaller generator coupled to the transmission may follow the same assembly methodology as stated above with respect to an earlier example implementation.
According to these more recently-described example implementations, a method of operation may be as follows. The SCS may be online and command the GTE’s primary auxiliary equipment to come online, which may result in fuel pumps and lube pumps to start. The GTE starter motor may then be functioned, allowing the GTE to reach an idle speed, after which the electric motor coupled to the starter gear may be disengaged and its power may be isolated. Once the power output shaft is functioned, and the GTE torque and power are transferred to the transmission, the clutches may be operated allowing the multistage pump and electric generator to be engaged and start rotating. The power from the electric generator may be then converted to DC through an AFE rectifier as described above, and distributed over a common DC bus. The power may be then distributed over the hydraulic fracturing unit and sent to drives that are controlling the speed of electric motors.
As previously described, a hydraulic fracturing unit (such as the hydraulic fracturing units 102, 220 previously described) may include a gas turbine engine. The performance of a gas turbine engine is dependent on the conditions under which the gas turbine engine operates. For example, ambient air pressure and temperature are large factors in the output of the gas turbine engine, with low ambient air pressure and high ambient temperature reducing the maximum output of the gas turbine engine. Low ambient pressure and/or high ambient temperature reduce the density of air, which reduces the mass flow of the air supplied to the intake of the gas turbine engine for combustion, which results in a lower power output. Some environments in which hydraulic fracturing operations occur are prone to low ambient pressure, for example, at higher elevations, and/or higher temperatures, for example, in hot climates. In addition, gas turbine engines are subject to damage by particulates in air supplied to the intake. Thus, in dusty environments, such as at many well sites, the air must be filtered before entering the intake of the gas turbine engine. However, filtration may reduce the pressure of air supplied to the intake, particularly as the filter medium of the filter becomes obstructed by filtered particulates with use. Reduced power output of the gas turbine engines reduces the pressure and/or flow rate provided by the corresponding hydraulic fracturing pumps of the hydraulic fracturing units. Thus, the effectiveness of a hydraulic fracturing operation may be compromised by reduced power output of the gas turbine engines of the hydraulic fracturing operation.
To generate additional power from an existing gas turbine, an inlet air conditioning system may be used. The air conditioning system may increase the airstream density by lowering the temperature of the airstream. This increases the mass flowrate of air entering the compressor, resulting in increased efficiency and power output of the gas turbine. An air conditioning system may include, for example, but not limited to, a chiller, an evaporative cooler, a spray cooler, or combinations thereof, located downstream of an inlet filter house within an inlet assembly of the gas turbine. Some air conditioning systems, however, add resistance to the airstream entering the compressor. This resistance may cause a pressure drop in the inlet assembly. Reduced gas turbine efficiency and power output may result from inlet assembly pressure drop.
The higher the inlet assembly pressure drop, the lower the efficiency and power output of the gas turbine. Typical pressure drop values across the gas turbine inlet assembly for power generation varies from about two (2) to about five (5) inches of water column (about five to about 12.7 centimeters of water). This includes the pressure drop across the air conditioning system, which varies from about 0.5 inches to about 1.5 inches of water column (about 1.27 to about 3.8 centimeters of water). Depending on the size of the gas turbine frame, the value of this pressure drop adversely affects the gas turbine output. For example, a gas turbine could lose up to 5% of rated output power from the pressure drop alone if the altitude and temperature remained at ISO conditions. Any change in temperature and/or pressure from ISO rated conditions could increase the rated output power loss. Every point of efficiency and power, however, is essential in the competitive business of power generation or the variety of other uses for mechanical drive gas turbines.
Accordingly, some embodiments of the present disclosure are generally directed to systems and methods for increasing the efficiency of operation of a gas turbine, for example, during operation in a wide variety of ambient conditions and/or under fluctuating loads. In some embodiments, a system for increasing the efficiency of a conventional gas turbine having an inlet assembly and a compressor, the inlet assembly being located upstream of the compressor, may include a housing, an air treatment module, and at least one air conditioning module. As contemplated and discussed above, performance losses may be expected at increased temperatures, increased altitude, and/or increased humidity when using a dual fuel turbine system in a mobile application that is configured to drive a reciprocating hydraulic fracturing pump or drive a generator as part of a gen-set. These environmental conditions may lead to the air being less dense, which may adversely affect turbine system performance as the turbine mass air flow through the air intake axial compression stages are directly proportional to the turbines performance output. The air treatment module may include one or more air conditioning modules that may condition input air to effect a desired increase in the mass flow of air through the air intake axial compression stages of the turbine.
According to some embodiments, the housing may be configured to channel an airstream towards the inlet assembly, the housing being positioned upstream of the inlet assembly, which channels the airstream to the compressor. The air treatment module may be positioned at a proximal end of the housing and may include a plurality of inlet air filters and at least one blower in fluid communication with an interior of the housing and configured to pressurize air entering the air treatment module. The at least one conditioning module may be mounted downstream of the air treatment module and may be configured to adjust the temperature of the airstream entering the compressor, such that the airstream enters the air conditioning module at a first temperature and exits the air conditioning module at a second temperature.
Referring to
In some embodiments, the air treatment system 410 may be incorporated into a hydraulic fracturing unit (such as hydraulic fracturing units 102, 220, previously described). For example, a hydraulic fracturing unit may include a trailer and a hydraulic fracturing pump to pump fracturing fluid into a wellhead, with the hydraulic fracturing pump connected to the trailer. The hydraulic fracturing unit also may include a gas turbine to drive the hydraulic fracturing pump, for example, via a gearbox, and the air treatment system 410, in some embodiments, may be used to increase the efficiency of the gas turbine 412. Hydraulic fracturing may be performed generally at any geographic location and during any season of the year, often in harsh environmental conditions. As a result, hydraulic fracturing may occur under a wide variety of ambient temperatures and pressures, depending on the location and time of year. In addition, the load on the hydraulic fracturing pumps and thus the gas turbine engines may change or fluctuate greatly, for example, depending on the build-up and release of pressure in the formation being fractured. In some embodiments, the air treatment system 410 may be configured to increase the efficiency of operation of a gas turbine, for example, during operation in a wide variety of ambient conditions and/or under fluctuating loads. As referenced above, performance losses may be expected at increased temperatures, increased altitude, and/or increased humidity when using a dual fuel turbine system for a mobile hydraulic fracturing unit configured to drive a reciprocating hydraulic fracturing pump via a gearbox or drive a generator as part of a gen-set. These environmental conditions may lead to the air being less dense, which may adversely affect turbine system performance as the turbine mass air flow through the air intake axial compression stages are directly proportional to the turbines performance output. In some embodiments, the air treatment system 410 may include one or more air conditioning modules that may condition input air to effect a desired increase in the mass flow of air through the air intake axial compression stages of the gas turbine, thereby at least partially mitigating or overcoming any performance losses of the gas turbine of a hydraulic fracturing unit due to increased temperatures, increased altitude, and/or increased humidity, while being able to respond to fluctuating loads
In some embodiments, the air treatment system 410 may include a housing 420, an air treatment module 430, and/or at least one air conditioning module 450. Optionally, the air treatment system 410 may further include a filter module 470 positioned intermediate the at least one conditioning module 450 and the input side of the gas turbine. As contemplated and discussed above, performance losses may be expected at increased temperatures, increased altitude, and/or increased humidity, for example, when using a dual fuel turbine system in a mobile application that is configured to drive a reciprocating hydraulic fracturing pump or drive a generator as part of a gen-set. These environmental conditions may lead to the air being less dense. One skilled in the art will appreciate that the relative density of air may be an important factor for a turbine as turbine mass air flow through the air intake axial compression stages may be directly proportional to the turbine’s performance output. The air treatment system 410 described herein may allow for the selective conditioning of air, which may affect a desired increase in air density of air entering the intake of the turbine. As described in more detail below, the air treatment module 430 and/or the at least one air conditioning module 470 of the air treatment system may filter air entering the air treatment system, may boost the pressure of air entering the air treatment system, and may lower the temperature of the air entering the air treatment system air to increase the operating efficiency of the turbine.
As illustrated, the example housing 420 may be configured to channel an airstream towards the inlet assembly of the turbine and may be positioned upstream of the input side of the turbine, which channels the airstream to the compressor. The housing 420 may have a shape that is configured for allowing for structural integration with the inlet assembly of the turbine. The integration of the inlet assembly of the turbine and the housing may allow for more controlled flow of the airstream flowing through the air treatment module 430 and the air conditioning module 450 and then flowing to the inlet assembly of the turbine. The housing 420 may be joined to the inlet assembly of the turbine via a plurality of connection means, such as, but are not limited to, welding, bolting, other fastening methods, or combinations thereof. The housing 420 may be formed of or include any material(s) capable of supporting the air treatment module and/or the air conditioning module. Such material(s) may include, for example, but are not limited to, a metal, an alloy, and/or other structural materials as will be understood by those skilled in the art.
The air treatment module 430 may include a plurality of inlet air filters or pre-cleaners 432 and at least one blower fan 435 configured to pressurize air. In some embodiments, the air treatment module 430 may be positioned at a proximal end 422 of the housing 20. The plurality of inlet air filters 432 may be in fluid communication with a first internal chamber 434 of the air treatment module, and the at least one blower fan 435 may be mounted in the first internal chamber 434 to pressurize air entering the first internal chamber 434 via the plurality of inlet air filters. In some embodiments, it is contemplated that plurality of inlet air filters may knock down debris, including mud, snow, rain, leaves, sawdust, chaff, sand, dust, and the like. As shown, the inlet air filters 432 may be configured to continuously or intermittently eject debris before reaching an optional filter module 470 that may be mounted internally within the housing, for example, without the need for further cleaning or shutting-down the unit to replace one or more of the plurality of inlet air filters.
As one skilled in the art will appreciate, to compensate for the pressure drop through the plurality of inlet air filters and to boost the pressure and flow of the air to the turbine, the at least one blower fan 435, which may be operated by an electrical or hydraulic motor, may be installed to bring the overall airflow up to a desired air feed rate, such as, for example and without limitation, about 28,000 CFM, to increase the inlet pressure at the inlet of the turbine with a resultant increase in efficiency of the turbine. Without limitation, in the schematic example shown in
It is contemplated that the at least one blower fan 435 may pressurize the air exiting the air treatment module to a degree sufficient to at least partially overcome the pressure losses associated with passing through the upstream plurality of air filters 432 and through the downstream air conditioning module 450 and, if used, a downstream filter module 470 positioned upstream of the at least one conditioning module, and any other losses the system may encounter, such as rarefication of the inlet air to the blower. In such embodiments, the downstream filter module 470 may be a conventional high-efficiency filter, such as, and without limitation, a conventional vane inlet with a low cartridge- or bag-type pre-filter that would be suitable for periodic cleaning and changing.
It is contemplated that the at least one blower fan 435 may be oversized to allow for further pressurization of the air at the downstream inlet of the turbine or engine. Oversizing may allow for suitable compensation for the loss of atmospheric pressure and air density, for example, with increased elevation. The change in pressure due to a change in elevation may be calculated via the following equation:
where:
- P = local atmospheric pressure;
- Pb = static pressure at sea level;
- Tb = temperature at sea level;
- Lb = temperature lapse rate;
- Hb = elevation at sea level;
- H = local elevation;
- R* = universal gas constant;
- g0 = gravity; and
- M = molar mass of air.
From the calculated pressure, the ideal gas law may be used to calculate a new density of the air at the constant atmospheric pressure.
where:
- P = absolute pressure;
- p = density;
- T = absolute temperature; and
- RSP = specific gas constant.
Referring now to
The increase in power results from the temperature decreasing and holding the air pressure constant. The ideal gas law equation may be used to calculate the density of the air as a function of the change in temperature. As may be seen from the table illustrated in
Referring to
The at least one air conditioning module 450 for adjusting the temperature of the airstream passing thorough the housing and toward the input side of the gas turbine may be mounted downstream of the air treatment module 430. The airstream enters the at least one air conditioning module 450 at a first temperature and exits the air conditioning module at a second temperature. The at least one air conditioning module 450 may have a conventional form such as a chiller. One skilled in the art will appreciate that other forms of conventional air conditioning modules are contemplated. The specific form of the at least one air conditioning module may be determined in part from the configuration of the gas turbine.
In some embodiments, the at least one conditioning module 450 may include at least one chiller module 455. The chiller module 455 may include a conventional arrangement of a plurality of condenser coils 456 disposed in the housing and that are configured to span the substantial width of the housing, such that the airstream passes through and/or around the plurality of condenser coils 456 to effect a desired lowering of the temperature of the airstream that is directed downstream toward the input side of the gas turbine. The plurality of condenser coils 456 may be in communication with a source of pressurized chilled refrigerant. The refrigerant may be any conventional refrigerant, such as, without limitation, R22, R410a, and the like as will be understood by those skilled in the art. In one example, the refrigerant fluid may be cooled to about 45° F., but it is contemplated that the desired coolant temperature may be changed to suit varying operating conditions as desired.
It is contemplated that the at least one air conditioning module 450 may decrease the temperature of the airstream entering the inlet assembly of the gas turbine to increase the efficiency and power output. In one exemplary aspect, the at least one conditioning module 450 may preferably decrease a temperature of the airstream by between about 2 and 20° F. and optionally between about 5 and 10° F. In some applications, increasing the efficiency and/or the power output of the gas turbine may lead to more efficient operations. For example, in a hydraulic fracturing operation including a plurality of hydraulic fracturing units, each operating a gas turbine to supply power to drive fracturing pumps, such increases in efficiency and/or power output may facilitate reducing the number the gas turbines operating, while still providing sufficient power to meet fracturing fluid pressure and/or flow rate needs to complete the fracturing operation.
In various exemplary aspects, it is contemplated that, in elevational cross-sectional view, the plurality of condenser coils 456 of the chiller module 455 may have a planar shape, a W shape, a V shape, or other geometric shape. The chiller module 455 may further comprise a means for chilling the source of pressurized chilled refrigerant. The means for chilling the source of pressurized chilled refrigerant may be a conventional refrigeration cycle using a compressor 458 that is configured to supply pressurized chilled refrigerant to the plurality of coils. The compressor may include a plurality of compressors, which may include one or more of the following types of compressors: a reciprocating compressor, a scroll compressor, a screw compressor, a rotary compressor, a centrifugal compressor, and the like.
Optionally, the means for chilling the source of pressurized chilled supply may include at least one chill line carrying pressurized refrigerant that may be routed through and/or around a cold source. It is contemplated that the cold source may include at least one gas source in liquid form.
Optionally, the plurality of condenser coils 456 may be placed in an existing radiator package where the lube coolers and engine coolers for the gas turbine are housed. It is also optionally contemplated that the plurality of condenser coils 456 may be packaged along with the compressor and an expansion valve of a conventional refrigeration cycle system. It is contemplated that the heat rejection requirement of the plurality of condenser coils 456 may be higher than the heat rejection of the evaporator because the plurality of condenser coils 456 must also reject the heat load from the coupled compressors.
Referring now to
In some embodiments, ISO conditions of 59° F., 14.696 pounds per square inch atmospheric pressure, at sea level, and 60% relative humidity may be the baseline operating levels for control of the air conditioning system 410, as these are the conditions that are used to rate a turbine engine for service. As shown in
It is contemplated that in the event there is a loss of one or more control signals from the supervisory control system of the air conditioning system 410, the chillers and blowers may be configured to automatically revert to operation at maximum output as a failsafe and/or to ensure that operation of the coupled turbine is not ceased. During operation, the pressure transducers and temperature transducers may be configured to provide continuous or intermittent feedback to the supervisory control system. As described, during normal operation according to some embodiments, the supervisory control system may operate to detect the deficiency of the inlet airstream, such as a temperature and/or pressure drop, and may be configured to send control outputs to the blower fan motors and/or the at least one air conditioning module 450, for example, to condition the airstream to mitigate or overcome the environmental losses. For example, and without limitation, the supervisory control system may include, but is not limited to, PLC, micro-controllers, computer-based controllers, and the like as will be understood by those skilled in the art.
Similarly,
A hydraulic fracturing operation site often encompasses a large footprint with the number of wells or wellheads and supporting components. The supporting components take time to be transported and to be setup for utilization at the fracturing operation sites. Due to the large nature of many fracturing operations, there exists a continued challenge to reduce the environmental impact resulting from fracturing operations. Accordingly, some embodiments disclosed herein are configured to reduce the environmental impact of noise pollution produced by the fracturing operations.
Specifically, some embodiments of the present disclosure are generally directed to systems and methods for dampening and directional control of exhaust air flow from a gas turbine of, for example, a direct drive turbine fracturing system. According to some embodiments, a mobile fracking system may include a trailer including a rear end, a front end, a bottom end, and a top end defining therebetween an interior space, a gas turbine housed inside the trailer in the interior space, and an exhaust attenuation system configured to receive exhaust gas from the gas turbine via an exhaust duct. The exhaust attenuation system may be attached to a portion of the trailer and may include a lower elongated plenum having an inlet adjacent the proximal end configured to receive exhaust gas from the gas turbine exhaust duct of the gas turbine and an upper noise attenuation system that is movably connected relative to the distal end of the lower elongated plenum. The upper noise attenuation system may be selectively movable between a stowed position, in which an outlet end portion of the upper noise attenuation system is positioned proximate to the distal end of the lower elongated plenum, and an operative position, in which the upper noise attenuation system defines an upper elongated plenum in fluid communication with the distal end of the lower elongated plenum and in which an outlet of the upper noise elongated plenum is spaced away from the distal end of the lower elongated plenum at a second distance that is greater than the first distance.
In some embodiments, a hydraulic fracturing unit (such as the hydraulic fracturing units 102, 220, previously described) 510 may include a trailer 512, a gas turbine 514, and an exhaust attenuation system 520 configured to receive exhaust gas from the gas turbine 514. The hydraulic fracturing unit 510 may be referred to herein as a “mobile fracking system.”
The trailer 512 may house at least one or more of the following equipment: (1) an inlet plenum; (2) the gas turbine 514; (3) the exhaust attenuation system 520 to remove exhaust gas from gas turbine into the atmosphere, (4) a gearbox and/or transmission 516 connected to a rotary output of the gas turbine, and (5) a fluid pump 518 operatively connected to the output of the gearbox. Other components not shown in
One skilled in the art will appreciate that the gas turbine 514 may be configured to generate mechanical energy (such as the rotation of a shaft) from a hydrocarbon fuel source, such as natural gas, liquefied natural gas, condensate, and/or other liquid fuels. As schematically illustrated, the gas turbine shaft is connected to the gearbox such that the gearbox converts the supplied mechanical energy from the rotation of the gas turbine shaft to a downstream shaft assembly that is rotated at a desired speed and torque to the downstream mechanically connected fluid pump. The gas turbine may be a gas turbine, such as the GE family of gas turbines, the Pratt and Whitney family of gas turbines, or any other gas turbine, dual shaft gas turbine, and/or dual-fuel turbine that generates sufficient mechanical power for the production of the desired level of brake horsepower to the downstream fluid pump for fracking operations at one or more well sites.
The trailer 512 may also comprise gas turbine inlet filter(s) configured to provide ventilation air and combustion air via one or more inlet plenums (not shown) to the gas turbine. Additionally, enclosure ventilation inlets may be added to increase the amount of ventilation air, which may be used to cool the gas turbine and ventilate the gas turbine enclosure. The combustion air may be the air that is supplied to the gas turbine to aid in the production of mechanical energy. The inlet plenum may be configured to collect the intake air from the gas turbine inlet filter and supply the intake air to the gas turbine.
In one embodiment and referring to
It is contemplated that the exhaust attenuation system 520 will be constructed of materials that are capable of withstanding extreme temperatures, such as for example and without limitation, to about 1250° F. (676° C.), that are associated with exhaust gases exiting gas turbines.
In embodiments, the upper noise attenuation system 540 may be configured to be selectively movable between a stowed position and an operative, upright, position. In the stowed position, an outlet end portion 542 of the upper noise attenuation system is positioned proximate to the distal end of the lower elongated plenum, and, in the operative position, the upper noise attenuation system defines an upper elongated plenum 550 that is in fluid communication with the distal end of the lower elongated plenum. In this operative position, an outlet 552 of the upper noise elongated plenum is spaced away from the distal end of the lower elongated plenum at a second distance that is greater than the first distance. Further, it is contemplated that the upper noise attenuation system, in the operative position, may extend longitudinally away from the distal end of the lower elongated plenum about the exhaust axis.
The mobile fracking system affects a reduction in sound emission by increasing the effective length of the gas turbine exhaust stack. Attenuation of rectangular duct in the 63 Hz to 250 Hz octave frequency bands may be expressed as:
For example, and without limitation, and taken from Table 1 above, proposed exhaust system may affect a 40% increase in sound attenuation and a maximum in 1.2 dB in sound pressure by selective operative increase in the elongate length of the exhaust plenum from 16.1 ft. to 22.6 ft.
In embodiments, the mobile fracking system 510 may include a first plenum 522 configured to receive exhaust gas from the gas turbine. In this aspect, a first end of the first plenum is connected to, and in fluid communication with, an exhaust outlet of the gas turbine and a second end of the first plenum connected to, and in fluid communication with, the inlet of the lower elongated plenum. For example, the gas turbine may be mounted to or otherwise supported thereon the bottom surface of the trailer and the first plenum may extend longitudinally substantially parallel to the bottom surface.
Optionally, the upper noise attenuation system 540 may include at least one array of baffles 570 that are configured to attenuate noise. The array of baffles 570 may include a plurality of baffles 572 that are distributed parallel to a common axis and that define a plurality of slots 574 defined by and between the plurality of baffles. In one exemplary aspect, the at least one array of baffles 570 may be mounted therein a portion of the upper elongated plenum in communication with the exhaust gas passing therethrough the upper elongated plenum to the outlet to supplement the noise dampening capabilities of the noise attenuation system.
In embodiments and referring to
As exemplarily shown in the figures, the pair of opposed silencer hoods 546 may include an upper silencer hood 554 and a lower silencer hood 556 that are configured to cooperatively slideably engage relative to each other when moving therebetween the stowed position and the operative position. In this example, the respective opposed upper and lower silencer hoods may be opened in a sequential manner. First, the upper silencer hood may be raised independently from the lower silencer hood. As shown, an anchor point mounted on a back surface of the planar surface of the upper silencer hood proximate a bottom edge of the back surface may be connected to a wire that is operative connected to a spooling system that is configured for selective movement of the connected silencer hood between the stowed and operative positions. In operation, the spooling system is operated to open or otherwise urge the upper silencer hood to the operative position and may comprise a winch, such as, for example and without limitation, an electric winch, a hydraulic winch, a pneumatic winch, and the like. It is contemplated that, once the upper silencer hood is in the operative position, tension may be maintained on the wire to aid in maintaining the upper silencer hood in the operative position until the upper silencer hood is lowered to the stowed position for transport. Optionally, a mechanical limit switch on the spooling system that may be configured to determine distance the wire is required to move to open and close the respective silencer hoods 546.
Similarly, the lower silencer hood 556 may be raised independently from the upper silencer hood 554. As shown, an anchor point mounted on a back surface of the planar surface of the lower silencer hood proximate a bottom edge of the back surface may be connected to a wire that is operative connected to the spooling system. In operation, after the upper silencer hood is positioned in the operative position, the spooling system of the lower silencer hood may be operated to open or otherwise urge the lower silencer hood to the operative position. It is contemplated that, once the lower silencer hood is in the operative position, tension may be maintained on the wire to aid in maintaining the lower silencer hood in the operative position until the lower silencer hood is lowered to the stowed position for transport. In this example, the lower silencer hood would be lowered first in sequence when the respective opposed upper and lower silencer hoods are closed or otherwise moved to the stowed position.
As noted above, the respective upper and lower silencer hoods 554, 556 may be maneuvered to and about the operative and the stowed positions through the use of one or more actuators, such as linear actuators and/or rotary actuators, and in some embodiments, one or more cables and/or one or more mechanical linkages. In some embodiments, the one or more actuators may be electrically-actuated, pneumatically-actuated, and/or hydraulically-actuated (e.g., via hydraulic cylinders and/or hydraulic motors). For example, the respective upper and lower silencer hoods 554, 556 may be maneuvered to and about the operative and the stowed positions through the use of a spooling system comprising electrical, mechanical, and/or pneumatic winches that contain spooled wire that are connected to the anchor points strategically positioned on the respective upper and lower silencer hoods 554, 556.
Optionally, the exhaust attenuation system shown in
Similarly, the second pair of opposing retention braces 599 includes a third brace 600 spaced proximally from the first brace and mounted to exterior portions the lower elongated plenum and a fourth brace 602 spaced proximally from the first brace and mounted to an opposed exterior portions of the lower elongated plenum. In this aspect, each brace of the second pair of opposing retention braces includes a bar 595 extending between a first end mount 596 and an opposing second end mount 597 such that, when the respective first and second end mounts are positioned therein the lower elongated plenum, the bar is spaced from an exterior surface of the lower elongated plenum and defines a slot 598 that is sized and shaped for receipt of respective side surfaces of the pair of silencer hoods when the pair of silencer hoods is positioned in the stowed position.
In embodiments, the upper noise attenuation system 540 may include at least one array of baffles configured to attenuate noise that is mounted therein at least a portion of the planer surface of at least one or in each of the opposed silencer hoods.
In other embodiments and referring to
In this aspect, to operatively move or otherwise urge the elongated conduit 610 about and between the stowed and operative positions, the upper noise attenuation system 540 may include at least one guide 620 mounted to an exterior surface (e.g., at an upper end thereof) of the lower elongated plenum 530. As will be appreciated, the guide 620 may define an elongated enclosed slot extending parallel to the exhaust axis. A rod 622 having a distal end mounted to an outermost edge surface of the outlet end 612 of the elongated conduit 610 may be provided that is configured for operative slideably receipt therein the slot of the guide 620. To operatively move the rod 622 and thereby move the elongated conduit 610 relative to the lower elongated plenum 530, a means for selective axial movement of the rod 622 and thus for movement of the elongated conduit 610 may be provided for selective movement of the elongated conduit 610 between the stowed position (see, e.g.,
As illustrated in
In this embodiment, the upper noise attenuation system may include at least one array of baffles configured to attenuate noise that may be mounted therein an outlet end of the elongated conduit.
It is contemplated that the means for selective axial movement of the rod for selective movement of the elongated conduit 610 between the stowed position and the operative position of the elongated conduit 610 may comprise one or more actuators, such as linear actuators and/or rotary actuators, and in some embodiments, one or more cables and/or one or more mechanical linkages. In some embodiments, the one or more actuators may be electrically-actuated, pneumatically-actuated, and/or hydraulically-actuated (e.g., via hydraulic cylinders and/or hydraulic motors). For example, selective movement of the elongated conduit 610 between the stowed position and the operative position of the elongated conduit 610 may be provided by the spooling system described above. In this aspect, the spooling system may comprise electrical, mechanical, and/or pneumatic winches that contain spooled wire and that are configured to spool wire onto each drum via the pulleys to affect the axial movement of the rod.
Optionally, the exhaust attenuation system 520 may further comprise a supervisory control system that is configured to utilize a series of digital input and output signals that will result in the controlled operation of the upper noise attenuation system 540. In this aspect, the exhaust attenuation system 520 may comprise a plurality of positional feedback sensors in communication with the supervisory control system. The positional feedback sensors are operatively mounted to respective portions of the upper noise attenuation system 540 such that the sensors may actuate when the upper noise attenuation system 540 is positioned in the stowed position and when in the operative, upright, position.
Each positional feedback sensor may comprise, for example and without limitation, a digital proximity switch that is configured to actuate when the positional feedback sensor’s electromagnetic detection field comes in contact with a portion of the metallic surface of the exhaust stack. Upon actuation, each digital proximity switch is configured to send a digital signal to the supervisory control system indicative of the position of the respective upper and lower silencer hoods 554, 556 or, optionally, the respective position of the elongated conduit 610 relative to the distal end of the lower elongated plenum.
Optionally, it is contemplated that the positional feedback sensor may be an analog position sensor that is configured to provide positional feedback to the supervisory control system of the positions of the respective upper and lower silencer hoods 554, 556 or, optionally, the respective position of the elongated conduit 610 relative to the distal end of the lower elongated plenum. In this exemplary aspect, the analog position sensor may be configured to transmit a scaled current or voltage signal that depending on the value allows the control system to identify the accurate position of the upper noise attenuation system 540. An exemplary analog position sensor, such as a Sick absolute encoder, models AFS/AFM60 SSI, would be suitable for this application.
The positional feedback sensors allow the operator to know the position of the respective upper and lower silencer hoods 554, 556 or, optionally, the respective position of the elongated conduit 610 relative to the distal end of the lower elongated plenum and to further allow for the protection of equipment on the gas turbine skid. For example, the supervisory control system may generate an interlock signal that would prohibit the ignition of the gas turbine engine upon receipt of a signal from the respective positional feedback sensors that indicates that the upper noise attenuation system 540 is in the closed position. Thus, the interlock signal preventing turbine operation into a sealed cavity prevents the possibility of serious damage to the turbine engine due to undesired backpressure.
In operational aspects, it is contemplated that the upper noise attenuation system 540 may be actuated to move between the stowed and operative positions by manual operation of a physical lever. In this aspect, and if the spooling system includes a pneumatic winch, the selective actuation of the manual level may allow for the flow of air to the pneumatic motor resulting in rotary motion at the winch. Optionally, if the spooling system includes a hydraulic winch, the selective actuation of the manual level may allow for the flow of hydraulic oil into the stator of the hydraulic motor to produce the desired rotary motion and torque to actuate the upper noise attenuation system 540. In a further, exemplary aspect, if the spooling system includes an electrical winch, a switching device may be provided that is configured to allow for the selective application of current to the electric winch motor. The switching device may exemplarily be in the form of a toggle switch that allows the electrical circuit to the motor to be completed upon actuation such that the electric motor performs the desired rotary motion.
In a further optional aspect, the supervisory control system of the exhaust attenuation system 520 may comprise a SCADA (supervisory control and data acquisition) system. Exemplarily, if pneumatic and/or hydraulic winches are used, a directional control valve with an electrical coil may be positioned between the respective pressurized sources of air or oil and the downstream pneumatic or hydraulic motors. Operationally, an operation signal transmitted or outputted to the directional control valve from the SCADA system upon operator input. In this aspect, the operation signal could be a PWM signal with reverse polarity. For example, when the operator pushes an input on a human machine interface, which is identified by the programmable logistical controller, and the necessary output operation signal is sent to the directional control valve that allows for proportional flow of the required air or oil media to the winch motor. Optionally, this methodology may also be used for an electrical winch but, in this aspect, the output operation signal would energize a relay that allows for low voltage, high current power to reach the electrical motor and perform the proportional operation function. It is contemplated that these actuation functions may be made fully autonomous by implementing a start-up sequence such that, when the operator selects to start the unit, a series of sequenced signal outputs are driven around the frac pump trailer that will verify that the exhaust attenuation system 520 is in the open, operative position, the auxiliary power is verified to be on line, the necessary safety and communication checks performed, and then the gas turbine is allowed to start. In this exemplary aspect, a single input to actuate the exhaust attenuation system 20 to move to the open, operative position may initiate the issuance of a series of outputs from the SCADA system, which may save the operator time and may reduce complexity of how to individually perform these sequential outputs.
During fracturing operations, high and low frequency torsional vibration is a common occurrence through the driveline. Such torsional vibration is typically generated via the operation of a reciprocating pump. Reciprocating pumps are driven to pump “slugs” of fluid with as the pump reciprocates or cycles. The speed and operating pressure of the pump influences the amount of fluid pumped downstream of the pump. As the reciprocating pump is cycled, movement of the slugs create pressure fluctuations within fluid downstream of the pump. This pressure fluctuation may create “hydraulic fluid pulsation” within the pump that is added to the operating pressure of the pump. The hydraulic fluid pulsation may be transferred upstream to driving equipment used to drive the pump in the form of torque output variances. The driving equipment may include one or more components including, but not limited to, a driveshaft, an engine, a transmission, or a gearbox.
As noted, the nature of the suction and discharge strokes of the reciprocating pump generate variable torque spikes that originate from the discharge of high pressure fluid and may migrate through the drive line and cause damage and premature wear on the driveline components including the prime mover. Problematically, each reciprocating pumps operating in the field generally have their own torsional vibration frequency and amplitude profile that is dependent upon the selected operational pressure and rate. Another problem arises when a group of reciprocating pumps are connected to a common discharge line. In this operational scenario, reciprocating pumps may begin to synchronize such that the natural sinusoidal wave form of one pump will begin to mirror that of another pump from the group, which promotes pressure spikes and torsional distortion of even higher amplitude to pulsate through the drive lines.
The torque output variances may create shock loading in the pump and in the driving equipment upstream from the pump. This shock loading may shorten the life of the driving equipment including causing failure of one or more components of the driving equipment. In addition, driving equipment such as combustion engines, e.g., gas turbine engines, have a movement of inertia, natural damping effects, and stiffness coefficients. Some driving equipment may have low natural damping effects that may allow for torsional resonance interaction within the driving equipment and/or between the driving equipment and the pump. This torsional resonance may shorten the life of the driving equipment including causing failure of one or more components of the driving equipment.
Thus there is a need to provide protection of hydraulic drive line fracturing equipment from imposed high frequency/low amplitude and low frequency/high amplitude torsional vibrations.
This disclosure relates generally to vibration dampening assemblies for use with pump systems including a reciprocating pump and driving equipment configured to cycle the pump. The vibration dampening assemblies may include single mass flywheel(s) and/or torsional vibration dampener(s) to reduce or eliminate upstream shock loading and/or dampen torsional resonance from reaching the driving equipment. As a result, the vibration dampening assemblies may reduce or eliminate pump imposed high frequency/low amplitude and low frequency/high amplitude torsional vibrations.
According to some embodiments, a single mass flywheel or a series of single mass flywheels along the drive-train system components between the gear box or transmission and input shaft of a reciprocating pump may be used to reduce output speed fluctuations that may cause vibrational and torsional effects on the gearbox and engine. Further, at least one torsional vibration dampener may be connected to the drive-train system to dampen the harmonic effects of the reciprocating pump. According to some embodiments, the at least one flywheel and the at least one torsional damper may not require electrical control to be able to function, but it is contemplated that electrical sensors and instrumentation may be present to monitor the condition of the drive line.
Referring now to
The driving equipment 750 is illustrated as a power transfer case. In some embodiments, the driving equipment 750 includes a driveshaft, a transmission, a gearbox, or an engine, e.g., an internal combustion engine or a gas turbine engine. The driving equipment 750 includes an output shaft 760 that has an output flange 762. The driving equipment 750 is configured to rotate the output shaft 760 about a longitudinal axis thereof. The driving equipment 750 may include an engine and a transmission, gearbox, and/or power transfer case that may be configured to increase a torque and decrease a rotational speed of the output shaft 760 relative to a driveshaft of the engine or that may be configured to decrease a torque and increase a rotational speed of the output shaft 760 relative to a driveshaft of the engine. The pump 860 includes in input shaft 870 having an input flange that is configure to receive input from the driving equipment 750 in the form of rotation of the input flange about a longitudinal axis of the input shaft 870.
The driveshaft 800 has a driving or upstream portion 810, a driven or downstream portion 840, and a central portion 830 between the upstream and downstream portions 810, 840. The upstream portion 810 includes an upstream flange (not shown) that is connected to the output flange 762 of the driving equipment 750 such that the upstream portion 810 rotates in response or in concert with rotation of the output shaft 760. The central portion 830 is secured to the upstream portion 810 and rotates in concert therewith. The downstream portion 840 is secured to the central portion 830 and rotates in concert therewith. The downstream portion 840 includes a downstream flange 842 that is connected to an input flange of the pump 860 such that the input flange rotates in response or in concert with rotation of the driveshaft 800. The downstream portion 840 may also include a spindle 844 adjacent the downstream flange 842. The upstream flange (not shown) may be similar to downstream flange 842 and the upstream portion 810 may include a spindle (not shown) that is similar to the spindle 844 of the downstream portion 840.
In some embodiments, the output shaft 760 of the driving equipment 750 is offset from the input shaft 870 of the pump 860 such that the longitudinal axis of the output shaft 760 is out of alignment, or is not coaxial with, the longitudinal axis of the input shaft 870. In such embodiments, the upstream portion 810 or the downstream portion 840 may include a constant velocity (CV) joint 820, 850 between the spindle 844 and the central portion 830. The CV joints 820, 850 allow for the output shaft 760 to be operably connected to the input shaft 870 when the output and input shafts 760, 870 are offset from one another.
During operation, the output shaft 760 is rotated by the driving equipment 750 to rotate the input shaft 870 of the pump 860 such that the pump 860 is driven to pump slugs of fluid. Specifically, the driving equipment 750 is configured to rotate the input shaft 870 at a constant velocity such that the pump 860 provides a constant flow of fluid. As the pump 860 pumps slugs of fluid, the pulses of the slugs of fluid create a pulsation pressure that adds to the nominal operating pressure of the pump 860.
With additional reference to
The hydraulic fluid pulsation describe above may be transferred upstream from the pump 860 to the driving equipment 750 through the driveshaft 800. Specifically, the hydraulic fluid pulsation results in torque variations in a crank/pinion mechanism of the pump 860 that are transferred upstream as torque output variations at the input shaft 870 of the pump 860. These torque output variations may create a torsional shock TS at the output flange 762 of the output shaft 760. A single large torsional shock TS may damage components of the driving equipment 750. In addition, an accumulation of minor or small torsional shocks TS may decrease a service life of one or more of the components of the driving equipment 750.
With continued reference to
As the output shaft 760 rotates the driveshaft 800, the flywheel 722 rotates in concert with the output shaft 760. As shown in
The angular momentum of the flywheel 722 may be calculated as a rotational kinetic energy “KE” of the flywheel 722. The “KE” of the flywheel 722 may be used to absorb or eliminate a percentage of the torsional shock TS. The “KE” of the flywheel 722 is a function of the moment of inertia “I” of the flywheel 722 and the angular velocity “ω” of the flywheel 722 which may be expressed as:
As noted above, the driving equipment 750 is configured to rotate at a constant angular velocity “ω” such that with a known “KE” or a known moment of inertia “I” the other of the “KE” or the moment of inertia “I” may be calculated. In addition, the moment of inertia “I” of the flywheel 722 is dependent on the mass “m” and the radial dimensions of the flywheel 722 and may be expressed as:
where r1 is a radius of rotation and r2 is a flywheel radius as shown in
The dimensions and mass of the flywheel 22 may be sized such that the flywheel 722 has a “KE” similar to a “KE” of an anticipated torque variance above a nominal operating torque of the pump 860. In some embodiments, the flywheel 722 maybe sized such that the “KE” of the flywheel 722 is greater than an anticipated torque variance such that the flywheel has a “KE” greater than any anticipated torque variance and in other embodiments, the flywheel 722 may be sized such that the “KE” of the flywheel 722 is less than the anticipated torque variance such that the flywheel 722 is provided to absorb or negate only a portion of the anticipated torque variances. In particular embodiments, the flywheel 722 is sized such that the “KE” of the flywheel 722 is equal to the anticipated torque variance such that the flywheel 722 is provided to absorb or negate the anticipated torque variance while minimizing a moment of inertia “I” of the flywheel 722.
The rotational kinetic energy “KE” of the torque variance is calculated from the specifications of a particular pump, e.g., pump 860, and from empirical data taken from previous pump operations as shown in
The “KE” of the torque variance may be used to size a flywheel 722 such that the flywheel 722 has a “KE” greater than or equal to the “KE” of the torque variance. Initially, equation (1) is used to calculate a desired moment of inertia “I” of the flywheel 722 solving for the “KE” of the torque variance created by the pressure spike PS for a given angular velocity “ω” of the flywheel 722. For example, the angular velocity “ω” of the output shaft 760 may be 152.4 radians/second with the “KE” of the torque variance created by the pressure spike PS being 12,097 N-m. Solving equation (1) provides a desired moment of inertia “I” of the flywheel 722 as 1.047 kg m2.
Once the desired moment of inertia “I” of the flywheel 722 is determined, equation (2) is used to determine dimensions of the flywheel 722 using desired moment of inertia “I”. As shown in
It will be appreciated that for a given system, the radius of rotation “r1” of the flywheel is set by a diameter of the spindle or flange on which the flywheel is secured, e.g., upstream flange of the upstream portion 810 or the flange 842 or the spindle 844 of the downstream portion 840 (
With additional reference to
where ρ is a mass density (lb./in3) of the material of the flywheel 722, ω is the angular velocity (rad/s) of the flywheel 722, and v is the Poisson’s ratio of the flywheel 722. As shown in
The installation or securement of the flywheel 722 to the pump system, e.g., to output flange 762 of the output shaft 760 (
where FB is a force (lbf) applied to the bolt 772, T is a torque (lb-ft) applied to the flywheel 722, AB is a bolt bearing stress area (in2) of the bolt 772, d is a diameter (ft) of the bolt hole 770, vs is a shear stress (psi) of each bolt 772, and vb is a bearing stress (psi) on the flywheel 722/bolt hole 770.
Continuing the example above, given a maximum torque “T” applied to the output flange 762 of 35,750 lb-ft with a bolt radius “rB” of 7.6 inches, the force applied to the bolts FB is 56,447 lbf. With the bolt bearing area of each bolt 772 being 0.785 in2 the shear stress vS of each of the 10 bolts is 7,187 psi. With the thickness of the flywheel “h” being 1.54 inches and a diameter of each bolt hole being 1.06 inches, the bearing stress vB is 3,885 psi.
From the calculated stresses of the example above and applying a factor of safety, a material for the flywheel 722 should have should have a tensile yield strength greater than or equal to 75 ksi. Examples of some suitable materials for the flywheel 722 are 1040 carbon steel, 1050 carbon steel, or Inconel® 718; however, other suitable metals or other materials may also be used. In addition, the materials sued for the bolts 772 and the nuts 776 should have a tensile strength greater than the calculated stresses. Examples of some suitable materials for the bolts 772 and the nuts 776 are Grade 8 carbon steel, Grade 5 carbon steel, or Grade G (8) steel; however, other suitable metals or other materials may also be used.
Referring briefly back to
As shown
Referring now to
With reference to
Referring now to
The configurations of the vibration dampening assembly 710 detailed above should be seen as exemplary and not exhaustive of all the configurations of the vibration dampening assembly 710. For example, the vibration dampening assembly 710 may consist of a flywheel 732 and a torsional vibration damper 734 as shown in
Conventional hydraulic fracturing pumping fleets have had fuel supplied from a single fuel source. In such fleets, when a hydraulic fracturing unit runs low on fuel (for example diesel), that unit may be shutdown while another stand-by hydraulic fracturing unit is brought in, refueled, and then put into service. Some inefficiencies included in this process are that the hydraulic fracturing unit once low on primary fuel must be stopped, refueled while another hydraulic fracturing unit is simultaneously being introduced into its place to make up for the loss of the pumping power that the hydraulic fracturing unit provides. This may affect the pumping performance within at least a portion of the subterranean well as requiring human intervention to perform the refueling, lining up suction and discharge valves. This may require multiple personnel to relay back the information so the process is performed in the correct series of steps. Using a single fuel source also limits the ability for the fracturing fleet to make it continuously through a section when low on fuel which results in delays in pumping completion.
In addition, in cases where the hydraulic fracturing unit needs to be taken offline for maintenance or replacement, significant disassembly is required to remove the hydraulic fracturing unit from its enclosure and to install a replacement hydraulic fracturing unit, potentially resulting in excessive downtime. In some cases, the entire trailer and enclosure may need to be removed from the site so a new, fully equipped trailer may be moved into place.
Thus, it may be seen that a need exists for more efficient ways of accessing the hydraulic fracturing units for maintenance purposes and/or replacement with minimum disruption to the system operations and the surrounding equipment. According, some embodiments of this disclosure are directed to a direct drive unit (DDU) positioner assembly, positioning system, removal system, and/or associated mechanisms for a hydraulic fracturing unit that will allow a DDU including a gearbox and a turbine engine connected to the gearbox to be detached from surrounding equipment and removed through the side of an enclosure housing the DDU. The system will allow for inspections, maintenance, or even a complete exchange of the direct drive unit with another if necessary.
In the illustrated embodiment, the gas turbine engine 925 is a Vericor Model TF50F bi-fuel turbine; however, the direct drive unit 923 may include other gas turbines or suitable drive units, systems, and/or mechanisms suitable for use as a hydraulic fracturing pump drive without departing from the disclosure. The gas turbine engine 925 is cantilever mounted to the gearbox 927 with the gearbox supported by the floor 941 of the enclosure 921. The gearbox 927 may be a reduction helical gearbox that has a constant running power rating of 5500 SHP and intermittent power output of 5850 SHP, or other suitable gearbox. It should also be noted that, while embodiments of the disclosure include systems and mechanisms for use with direct drive units 923 to operate fracturing pumping units 933, the disclosed systems and mechanisms may also be directed to other equipment within the well stimulation industry such as, for example, blenders, cementing units, power generators and related equipment, without departing from the scope of the disclosure.
As shown in
Exemplary loading calculations for sizing the guide rails 1005, 1007, 1009, 1011 are shown below and are based on the Vericor TF50F turbine parameters as follows: approximate turbine weight, 1475 lbs.; approximate fuel system weight, 85 lbs.; approximate gearbox weight, 4000 lbs.; for a total approximate weight of 5559 lbs. Various other parameters may be applicable based on the make, model, and size of the gas turbine engine 925.
Because of the arrangement the direct drive unit 923 including the gas turbine engine 925 cantilever mounted onto the gearbox 927 and extending in the longitudinal direction L1 from the gearbox, there is added load put onto the rear lateral guide rollers 1015 and the rear longitudinal guide rollers 1021, 1023 (the guide rollers mounted closest to the gas turbine engine). Accordingly, an increased load rating may be applied to the rear guide rollers 1015, 1021, 1023 if required. The calculation of the cantilever load and the reaction forces may be calculated with the formulas shown below, which may also be used for further design and implementation of the disclosed removal mechanisms.
- Maximum Reaction at the fixed end may be expressed as: RA = qL.
- where: RA = reaction force in A (N, lb), q = uniform distributed load (N/m, N/mm, lb/in), and
- L = length of cantilever beam (m, mm, in).
- Maximum Moment at the fixed end may be expressed as MA = - q L2/2
- Maximum Deflection at the end may be expressed as δB = q L4 / (8 E I).
- where: δB = maximum deflection in B (m, mm, in).
In one embodiment, the longitudinal guide rollers 1021, 1023 connected to the support structure 1027 of the gearbox 927 are positioned between each pair of the lateral guide rollers 1015, 1017 to ensure equal weight distribution over the platform 1003 and to avoid cantilever loading the platform. Different configurations of platforms, sliders, rails and mounts are contemplated and considered within the scope of the disclosure. The configurations of the DDU positioner assembly 1001 may vary to suit a particular DDU 923 with various alternative combinations of makes, model, and sizes of the gas turbine engine 925 and the gearbox 927.
In one embodiment, the guide rails 1005, 1007, 1009, 1011 are made from a steel composition that has been mill finished and shot blasted to protect the rail from the high heat environment within the turbine enclosure 921 and ensure strength retention under the exposed temperatures. In one embodiment, the platform 1003 is constructed out of a composite material; however, other materials are contemplated and considered within the scope of the disclosure, such as but not limited to, steel or stainless steel. The guide rails 1005, 1007, 1009, 1011, platform 1003, and/or other components of the DDU positioner assembly 1001 may be made of various other suitable materials without departing from the scope of the disclosure.
Once the gas turbine engine 925 is disconnected from the respective connections and the gearbox 927 is disconnected from the driveshaft 931, the DDU positioner assembly 1001 is operated to position the direct drive unit 923 for withdrawal from the enclosure 921. As shown in
In one embodiment, the DDU positioner assembly 2001 includes a platform 2003 that supports the gearbox 927 and has a top surface 2005, a bottom surface 2007, two sides 2008, and two ends 2010. The gearbox 927 is fixedly mounted to the top surface 2005 of the platform 2003. The platform 2003 is slidably mounted on the base 941 of the enclosure 921 with the bottom surface 2007 of the platform being in slidable engagement with the floor of the enclosure. In a first or operating position (
In one embodiment, the DDU positioner assembly 2001 includes a lubricator or lubrication system 2021 (
In one embodiment, the DDU positioner assembly 2001 includes drive fasteners 2041 mounted at one end 2010 of the platform 2003. In the illustrated embodiment, the drive fasteners 2041 include a bracket 2045 mounted to the floor 941 of the enclosure 921 and an impact screw 2047 operatively connected to the bracket and the platform 2003. The drive fasteners 2041 may have other components and be otherwise arranged without departing from the disclosure. Further, more or less than two drive fasteners 2041 may be provided without departing from the disclosure.
As shown in
The lifting mechanism 2061 may move the DDU 293 to the third position (
The embodiments disclosed herein include systems and methods for addressing many of the challenges associated with performing a hydraulic fracturing operation, including some challenges that are associated with the use of gas turbine engines to power the one or more pumps of the hydraulic fracturing system. While a number of embodiments of systems and components (and related methods) are described herein, it should be appreciated that other embodiments are contemplated that utilize a combination (including a subset) of features of one or more (or all) of the various embodiments that are particularly described. Thus, the description of the various embodiments should not be interpreted as limiting the particular combinations or subcombinations of features that may be utilized in other embodiments according to this disclosure. Moreover, the embodiments disclosed herein may also be relevant to hydraulic fracturing system that utilize prime movers that are not gas turbine engines (such as diesel engines, electric motors, etc.). Thus, unless otherwise required, the embodiments disclosed herein may be employed to improve the operations of hydraulic fracturing systems that do and that do not employ gas turbine engines.
The preceding discussion is directed to various exemplary embodiments. However, one of ordinary skill in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
In the discussion herein and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to ....” Also, the terms “connect,” “connects,” “couple,” “couples” and the like is intended to mean either an indirect or direct connection. Thus, if a first device couples or connects to a second device, that connection may be through a direct connection of the two devices, or through an indirect connection that is established via other devices, components, nodes, and connections.
This application is a continuation-in-part of U.S. Non-Provisional Application No. 18/148,209, filed Dec. 29, 2022, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/954,118, filed Sep. 27, 2022, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,598,263, issued Mar. 7, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/403,373, filed Aug. 16, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,560,845, issued Jan. 24, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/326,711, filed May 21, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,156,159, issued Oct. 26, 2021, which is a continuation U.S. Non-Provisional Application No. 17/213,802, filed Mar. 26, 2021, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,060,455, issued Jul. 13, 2021, which is a continuation of U.S. Non-Provisional Application No. 16/948,289, filed Sep. 11, 2020, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,002,189, issued May 11, 2021, which claims priority to and the benefit of U.S. Provisional Application No. 62/704,565, filed May 15, 2020, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM AND ASSOCIATED METHODS,” and U.S. Provisional Application No. 62/900,291, filed Sep. 13, 2019, titled “MOBILE GAS TURBINE INLET AIR CONDITIONING SYSTEM,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also a continuation-in-part of U.S. Non-Provisional Application No. 17/676,949, filed Feb. 22, 2022, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” which is a divisional of U.S. Non-Provisional Application No. 17/519,827, filed Nov. 5, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,415,056, issued Aug. 16, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/502,120, filed Oct. 15, 2021, titled “METHODS FOR NOISE DAMPENING AND ATTENUATION OF TURBINE ENGINE,” now U.S. Pat. No. 11,560,848, issued Jan. 24, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/498,916, filed Oct. 12, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,459,954, issued Oct. 4, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/182,325, filed Feb. 23, 2021, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 11,242,802, issued Feb. 8, 2022, which is a continuation of U.S. Non-Provisional Application No. 16/948,290, filed Sep. 11, 2020, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM AND METHODS FOR NOISE DAMPENING AND ATTENUATION,” now U.S. Pat. No. 10,961,914, issued Mar. 30, 2021, which claims priority to and the benefit of, U.S. Provisional Application No. 62/704,567, filed May 15, 2020, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM FOR NOISE DAMPENING AND ATTENUATION,” and U.S. Provisional Application No. 62/899,957, filed Sep. 13, 2019, titled “TURBINE ENGINE EXHAUST DUCT SYSTEM FOR NOISE DAMPENING AND ATTENUATION,” the disclosures of which are incorporated herein by reference in their entireties.
This is also a continuation-in-part of U.S. Non-Provisional Application No. 18/108,821, filed Feb. 13, 2023, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” which is a continuation of U.S. Non-Provisional Application No. 17/585,766, filed Jan. 27, 2022, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” which is a continuation of U.S. Non-Provisional Application No. 17/469,970, filed Sep. 9, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,280,331, issued Mar. 22, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/363,151, filed Jun. 30, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,149,726, issued Oct. 19, 2021, which is a continuation of U.S. Non-Provisional Application No. 17/213,562, filed Mar. 26, 2021, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,092,152, issued Aug. 17, 2021, which is a continuation of U.S. Non-Provisional Application No. 16/948,291, filed Sep. 11, 2020, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” now U.S. Pat. No. 11,015,594, issued May 25, 2021, which claims priority to and the benefit of U.S. Provisional Application No. 62/704,560, filed May 15, 2020, titled “SYSTEMS AND METHOD FOR USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER ASSEMBLY FOR SINGLE ACTING RECIPROCATING PUMP,” and U.S. Provisional Application No. 62/899,963, filed Sep. 13, 2019, titled “USE OF SINGLE MASS FLYWHEEL ALONGSIDE TORSIONAL VIBRATION DAMPER SYSTEM FOR SINGLE ACTING RECIPROCATING PUMP,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also a continuation-in-part of U.S. Non-Provisional Application No. 18/116,383, filed Mar. 2, 2023, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/976,095, filed Oct. 28, 2022, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/555,815, filed Dec. 20, 2021, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S Pat. No. 11,530,602, issued Dec. 20, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/203,002, filed Mar. 16, 2021, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,236,739, issued Feb. 1, 2022, which is a divisional of U.S. Non-Provisional Application No. 16/946,079, filed Jun. 5, 2020, titled “POWER SOURCES AND TRANSMISSION NETWORKS FOR AUXILIARY EQUIPMENT ONBOARD HYDRAULIC FRACTURING UNITS AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,989,180, issued Apr. 27, 2021, which claims the benefit of and priority to U.S. Provisional Pat. Application No. 62/899,971, filed Sep. 13, 2019, titled “AUXILIARY DRIVE SYSTEMS AND ALTERNATIVE POWER SOURCES,” the disclosures of which are incorporated herein by reference in their entireties.
This application is also continuation-in-part of U.S. Non-Provisional Application No. 18/147,880, filed Dec. 29, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” which is a continuation of U.S. Non-Provisional Application No. 17/936,885, filed Sep. 30, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,578,660, issued Feb. 14, 2023, which is a continuation of U.S. Non-Provisional Application No. 17/883,693, filed Aug. 9, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,512,642, issued Nov. 29, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/808,792, filed Jun. 24, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,473,503, issued Oct. 18, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/720,390, filed Apr. 14, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,401,865, issued Aug. 2, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/671,734, filed Feb. 15, 2022, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,346,280, issued May 31, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/204,338, filed Mar. 17, 2021, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 11,319,878, issued May 3, 2022, which is a continuation of U.S. Non-Provisional Application No. 17/154,601, filed Jan. 21, 2021, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,982,596, issued Apr. 20, 2021, which is a divisional of U.S. Non-Provisional Application No. 17/122,433, filed Dec. 15, 2020, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,961,912, issued Mar. 30, 2021, which is a divisional of U.S. Non-Provisional Application No. 15/929,924, filed May 29, 2020, titled “DIRECT DRIVE UNIT REMOVAL SYSTEM AND ASSOCIATED METHODS,” now U.S. Pat. No. 10,895,202, issued Jan. 19, 2021, which claims the benefit of and priority to U.S. Provisional Application No. 62/899,975, filed Sep. 13, 2019, titled “TURBINE REMOVAL SYSTEM,” the disclosures of which are incorporated herein by reference in their entireties.
Although only a few exemplary embodiments have been described in detail herein, those skilled in the art will readily appreciate that many modifications are possible in the exemplary embodiments without materially departing from the novel teachings and advantages of the embodiments of the present disclosure. Accordingly, all such modifications are intended to be included within the scope of the embodiments of the present disclosure as defined in the following claims. Any combination of the above embodiments is also envisioned and is within the scope of the appended claims. Therefore, the above description should not be construed as limiting, but merely as exemplifications of particular embodiments. Those skilled in the art will envision other modifications within the scope of the claims appended hereto.
Claims
1. A pumping unit, comprising:
- a gas turbine engine;
- an enclosure housing the gas turbine engine;
- an exhaust assembly connected to the gas turbine engine;
- an air intake duct connected to the gas turbine engine;
- an air treatment system connected to the air intake duct, the air treatment system comprising one or more inlet pre-cleaners configured to eject debris, each of the one or more inlet pre-cleaners having a cylindrical tubular portion configured to channel air toward the air intake duct;
- a gearbox operatively coupled to the gas turbine engine;
- a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox; and
- a pump comprising an input shaft operatively coupled to the second end of the drive shaft, wherein the gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pumping unit.
2. The pumping unit of claim 1, further comprising a trailer configured to support both the pump and the enclosure.
3. The pumping unit of claim 1, wherein the gas turbine engine is a dual fuel, dual shaft gas turbine engine.
4. The pumping unit of claim 1, wherein the gas turbine engine is cantilever mounted to the gearbox and the gearbox is supported by a floor of the enclosure.
5. The pumping unit of claim 1, further comprising a brake configured to stop rotation of the drive shaft.
6. The pumping unit of claim 1, wherein a longitudinal axis of the drive shaft is offset from a longitudinal axis of the input shaft of the pump.
7. The pumping unit of claim 1, further comprising an electric generator mechanically linked to the gearbox, the electric generator configured to convert electricity from mechanical energy generated by the gas turbine engine.
8. The pumping unit of claim 1, further comprising one or more torsional vibration dampers operably connected to the input shaft of the pump and configured to reduce tortional resonance within the gas turbine engine, the gearbox, the drive shaft, or the pump.
9. The pumping unit of claim 2, further comprising:
- auxiliary equipment comprising lubrication and cooling equipment driven by hydraulic motors to support operation of the hydraulic fracturing unit including the pump; and
- one or more hydraulic power arrangements configured to power the auxiliary equipment, each hydraulic power arrangement comprising a hydraulic power source including an electric motor configured to drive a plurality of pumps via a hydraulic pump drive to generate hydraulic power.
10. The pumping unit of claim 9, wherein the auxiliary equipment is powered by an electric power arrangement, the electric power arrangement comprising an electric motor located on a gooseneck area of the trailer, wherein the electric motor is configured to drive the auxiliary equipment.
11. A pumping unit, comprising:
- a chassis;
- an enclosure disposed on the chassis, the enclosure housing a gas turbine engine and a gearbox operatively coupled to the gas turbine engine, wherein the enclosure comprises: a first lateral side; a second lateral side; and a door mounted on the first lateral side proximate to the gas turbine engine;
- an exhaust assembly connected to the gas turbine engine;
- an air intake duct connected to the gas turbine engine;
- an air treatment system connected to the air intake duct, the air treatment system comprising one or more inlet pre-cleaners configured to eject debris particles via inertia of the debris particles;
- a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox; and
- a pump disposed on the chassis, the pump comprising an input shaft operatively coupled to the second end of the drive shaft, wherein the gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pumping unit.
12. The pumping unit of claim 1, wherein the gas turbine engine is a dual fuel, dual shaft gas turbine engine.
13. The pumping unit of claim 11, wherein the gas turbine engine is cantilever mounted to the gearbox and the gearbox is supported by a floor of the enclosure.
14. The pumping unit of claim 11, further comprising a brake configured to stop rotation of the drive shaft.
15. The pumping unit of claim 11, wherein a longitudinal axis of the drive shaft is offset from a longitudinal axis of the input shaft of the pump.
16. The pumping unit of claim 11, further comprising one or more torsional vibration dampers operably connected to the input shaft of the pump and configured to reduce tortional resonance within the gas turbine engine, the gearbox, the drive shaft, or the pump.
17. The pumping unit of claim 11, further comprising a fuel line connected to the pumping unit and configured to supply field gas from a fuel source to the gas turbine engine.
18. The pumping unit of claim 11, further comprising:
- auxiliary equipment comprising lubrication and cooling equipment driven by hydraulic motors to support operation of the hydraulic fracturing unit including the pump; and
- one or more hydraulic power arrangements configured to power the auxiliary equipment, each hydraulic power arrangement comprising a hydraulic power source including an electric motor configured to drive a plurality of pumps via a hydraulic pump drive to generate hydraulic power,
- wherein the auxiliary equipment is powered by an electric power arrangement, the electric power arrangement comprising an electric motor configured to drive the auxiliary equipment.
19. A hydraulic fracturing system comprising:
- a plurality of hydraulic fracturing units;
- a fuel line configured to supply fuel from a fuel source to the plurality of hydraulic fracturing units; and
- a first hydraulic fracturing unit of the plurality of hydraulic fracturing units comprising: a gas turbine engine; an enclosure housing the gas turbine engine; an exhaust assembly connected to the gas turbine engine; an air intake duct connected to the gas turbine engine; an air treatment system connected to the air intake duct, the air treatment system comprising one or more inlet pre-cleaners configured to eject debris; a gearbox operatively coupled to the gas turbine engine; a drive shaft having a first end and a second end, wherein the first end of the drive shaft is operatively coupled to the gearbox; and a pump comprising an input shaft operatively coupled to the second end of the drive shaft, wherein the gas turbine engine, the gearbox, the drive shaft, and the pump are disposed along a longitudinal axis of the pump, and wherein a longitudinal axis of the drive shaft is offset from a longitudinal axis of the input shaft of the pump.
20. The hydraulic fracturing system of claim 19, wherein the first hydraulic fracturing unit further comprises:
- auxiliary equipment comprising lubrication and cooling equipment driven by hydraulic motors to support operation of the hydraulic fracturing unit including the pump; and
- one or more hydraulic power arrangements configured to power the auxiliary equipment, each hydraulic power arrangement comprising a hydraulic power source including an electric motor configured to drive a plurality of pumps via a hydraulic pump drive to generate hydraulic power.
21. The hydraulic fracturing system of claim 19, wherein the gas turbine engine is a dual fuel, dual shaft gas turbine engine.
22. The hydraulic fracturing system of claim 19, wherein the fuel line is connected to the pump and configured to supply field gas from a fuel source to the gas turbine engine.
23. The hydraulic fracturing system of claim 20, wherein the auxiliary equipment is powered by an electric power arrangement, the electric power arrangement comprising an electric motor located on a gooseneck area of a trailer, wherein the electric motor configured to drive the auxiliary equipment.
Type: Application
Filed: Apr 5, 2023
Publication Date: Sep 21, 2023
Inventors: Tony Yeung (The Woodlands, TX), Ricardo Rodriguez-Ramon (The Woodlands, TX), Diankui Fu (The Woodlands, TX), Heber Martinez-Barron (The Woodlands, TX), Guillermo Rodriguez (The Woodlands, TX), Samir Nath Seth (The Woodlands, TX), Joseph Foster (The Woodlands, TX), Warren Zemlak (The Woodlands, TX), Nicholas Tew (The Woodlands, TX)
Application Number: 18/131,207
